42.0827.2042.09918Entergy Mississippi, LLC42.08340.06740.11740.147242.100319Q442.084Entergy Mississippi, LLC342024-04-15842.101Q442040.0682024-04-1540.11840.148142.085Entergy Mississippi, LLC242.10252142.086Q4342.10340.06940.1192024-04-1522Entergy Mississippi, LLC40.149642.087Q4442.105242024-04-15Entergy Mississippi, LLC26742.088true40.07040.12040.150542.106Entergy Mississippi, LLCQ42272024-04-15381842.08919642.107Q4492840.0712024-04-1540.121Entergy Mississippi, LLC42.09040.151742.10851029Entergy Mississippi, LLCQ442.0912024-04-15842.10940.07240.12240.15230Q4true42.0922024-04-1536Entergy Mississippi, LLC101142.1103142.09340.073Entergy Mississippi, LLC40.123Q41242.1112024-04-1540.1533242.094Q4111342.1122024-04-1577240.0747840.124Entergy Mississippi, LLC42.09540.15421442.11325.1Entergy Mississippi, LLCQ43792024-04-1542.0961542.11440.075Q440.125425.22024-04-1580Entergy Mississippi, LLC42.0975431642.1155Entergy Mississippi, LLC81Q45542.09840.07640.1262024-04-1540.1561742.11625419.112.05Q42735.2440.00740.03740.0872024-04-1512.06537.1Entergy Mississippi, LLC12.072835.2640.00840.03840.08837.26Q412.082024-04-152912.0940.00940.03940.089Entergy Mississippi, LLC712.10Q42024-04-153040.09040.01040.0402012.118887.1Entergy Mississippi, LLC12.123140.01140.04140.091Q47.292024-04-1512.13Entergy Mississippi, LLC3212.1440.01240.04240.0922010Q4202024-04-1513340.013240.04340.093112Entergy Mississippi, LLC322Q43440.01440.04440.0942024-04-1512438Entergy Mississippi, LLC5223540.01540.04540.09513Q422024-04-15335.0140.01640.04640.096Entergy Mississippi, LLC14442.133Entergy Mississippi, LLC14642.117242.13440.137Q417252024-04-1542.1182.01242.136321The Workiva PlatformEntergy Mississippi, LLC2242.1192.0240.1381826Q422.0142.1202.032024-04-1540.1391922.022742.1212.04Entergy Mississippi, LLC42.1222.05Q440.1402024-04-15202842.1232.06Entergy Mississippi, LLC42.1242.0740.14152Not Prepared29Q4212024-04-154842.1251240.15540.142Entergy Mississippi, LLC223042.1263Q442.1272024-04-1540.1434233142.128Entergy Mississippi, LLC12542.12940.144Q424322024-04-15642.130Entergy Mississippi, LLC40.145253342.131Q4262024-04-152742.13240.1462634Entergy Mississippi, LLC5021Q42024-04-156542.014740.05722Entergy Mississippi, LLC642.015823Q440.05872024-04-1542.0169242023117.18Entergy Mississippi, LLC42.0172102540.05931.19Q442.0183112024-04-15261042.01941240.060C00899927112942.02051428Entergy Mississippi, LLC3140.0611242.02129181342.0223040.0621442.023311.132151.242.02440.06332140.0042161.342.02513340.064171.442.0262O34531842.0272024-04-153540.06531942.028362042.02940.0663742024-04-15823835.1240.02740.07740.107Entergy Mississippi, LLC831540.15739437Q4842024-04-15174035.13140.02840.07840.10840.158168518382Entergy Mississippi, LLC418635.1440.02940.07940.109Q440.1591732024-04-154239872842.001Entergy Mississippi, LLC35.15440.03040.08040.11040.1601842.00240Q415.12024-04-15542.00335.1640.03140.08140.11140.16140.00119Entergy Mississippi, LLC42.0046Q435.175.140.03240.08240.1122024-04-1540.1622042.00540.0028Entergy Mississippi, LLC42.00635.1840.08340.03340.11340.16340.0032110Q442.0072024-04-151642.00835.191140.03440.08440.114Entergy Mississippi, LLC22640.16429391092135675003078635100142.009Q42122024-04-1535.2040.03540.08540.1157.0142.01123340.005Entergy Mississippi, LLC67.0242.012435.2240.03640.08640.116Q440.006242024-04-157.0342.0136Q412024-04-1542.0491727Entergy Mississippi, LLC42.05083Q41842.0512024-04-159442.0522Entergy Mississippi, LLC103441942.053Q4542024-04-1542.054205Entergy Mississippi, LLC642.055Q42024-04-1521742.056Entergy Mississippi, LLC42.057822Q442.0582024-04-15942.059falseEntergy Mississippi, LLC231042.060Q42024-04-1545.12442.061Entergy Mississippi, LLC42.062Q4252024-04-1542.063<span style="color:#000000;font-family:'Arial',sans-serif;font-size:9pt;font-weight:400;line-height:120%">12. See Entergy Mississippi's 2023 FERC Form 1 Notes to Financial Statements.</span>Entergy Mississippi, LLC42.06426Q4Q442.0656242.030Entergy Mississippi, LLCQ42024-04-1540.01740.04740.0977735Q442.0311262024-04-15Entergy Mississippi, LLC842.03240.01840.09840.048Entergy Mississippi, LLCQ4362024-04-159842.033Q42024-04-15Entergy Mississippi, LLC42.03440.01940.04940.099940Entergy Mississippi, LLCQ442.0352024-04-157640.02040.05040.100Q4102024-04-15Entergy Mississippi, LLC42.0377742.038Entergy Mississippi, LLCQ440.02140.05140.1012024-04-15113.142.03926Q41792024-04-15Entergy Mississippi, LLC42.04040.02240.05240.10221213.1Entergy Mississippi, LLCQ42024-04-1542.0413.2Q440.02340.05340.1032024-04-15Entergy Mississippi, LLC1131342.04212Entergy Mississippi, LLCQ442.0432024-04-1540.02440.05440.1044212.01Q441442.0442024-04-15Entergy Mississippi, LLC12.0242.04540.02540.05540.105Entergy Mississippi, LLCEntergy Mississippi, LLCQ42024-04-1512.0351542.046Q4142024-04-15Entergy Mississippi, LLC12.0440.02640.05640.10661627.142.04827.0142.0667.04535.0227.0240.1272742.0677.0527.03635.0342.06840.1287.062827.0442.0697.0727.052735.04340.1292942.0707.0827.06442.0717.09835.0527.07340.1303044.0142.0727.1054.02935.0642.07340.1317.113164.0342.0747.121035.0774.0440.1323242.0757.1384.0542.0767.141135.0840.1333394.06142.0777.15104.0721235.0942.07840.1347.1634114.0842.0797.1731335.10124.0940.1353542.0807.181342.0817.1941535.1140.1363614 C008999 Privilege License, Other Taxes, , 2023-01-012023-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 UFL-16 Urban Flood Lighting 2023-01-012023-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2023-01-012023-12-31 C008999 ATTALA, Distribution, Unattended 2023-01-012023-12-31 C008999 AIRPORT/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 COUNTRY CLUB/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 3.85% Series 2 2023-01-012023-12-31 C008999 ELTON RD, Distribution, Unattended 2023-12-31 C008999 2020 Planning CL20-005V Rep A1, RRE 2023-01-012023-12-31 C008999 ferc:SubsidiaryCompanySubheadingMember EMI New Nuclear, LLC 2023-01-012023-12-31 C008999 Asset Retirement Obligation - Fossil 2023-01-012023-12-31 C008999 C6ML300107: Rolling Fork - Onward 1ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2022-12-31 C008999 ferc:PenaltyTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CO1 LTSA Capitalization CT 101 2023-01-012023-12-31 C008999 FC21M053 - FOCUS - FA05 - 55F0575ferc:ElectricUtilityMember 2023-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2023-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2023-12-31 C008999 OTHER GENERAL & INTANGIBLE PLANTferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Downtown Jackson - Replace 1500 KVAferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Wolf Creek - Add 500kV Breakerferc:ElectricUtilityMember 2023-12-31 C008999 Mark-to-Market 2023-01-012023-12-31 C008999 Natchez S:  Replace J0855 XFMRferc:ElectricUtilityMember 2023-12-31 C008999 10%ferc:ElectricUtilityMember 2023-12-31 C008999 MS FEEDER INVESTMENT, 2024, CLINTONferc:ElectricUtilityMember 2023-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2023-01-012023-12-31 C008999 CARTHAGE (MS), Distribution, Unattended 2023-01-012023-12-31 C008999 See Footnote Detail 2023-01-012023-12-31 C008999 C6ML300043: Horn Lake - Greenbrookferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 President and Chief Executive Officer of Entergy Mississippi 2023-01-012023-12-31 C008999 PORT GIBSON, Distribution, Unattended 2023-01-012023-12-31 C008999 Batesville: Replace HV breaker J048 2023-01-012023-12-31 C008999 ALGS-10 Alternate Large General Service 2023-01-012023-12-31 C008999 Indianola: Replace Control House & 2023-01-012023-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 0 2023-01-012023-12-31 C008999 FAYETTE 2023-01-012023-12-31 C008999 ferc:JulyMember 0 2023-01-012023-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2023-01-012023-12-31 C008999 B(2), Edison Electric Institute (1) 2023-01-012023-12-31 C008999 TINNIN ROAD, Distribution, Unattended 2023-01-012023-12-31 C008999 HN1 - Hinds LTSA Capitalferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Entergy Services, LLC, Income Tax, , 2023-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2023-01-012023-12-31 C008999 FREEPORT, Transmission, Unattended 2023-01-012023-12-31 C008999 4.52% Series 2023-01-012023-12-31 C008999 C6ML300118: Onward - Redwood 115kVferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:PropertyTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:FuelTaxMember 2023-12-31 C008999 See footnote for allocation method details, 2023-01-012023-12-31 C008999 FANNIN ROAD, Distribution, Unattended 2023-12-31 C008999 Mark-to-Market 2023-01-012023-12-31 C008999 PICKENS, Distribution, Unattended 2023-01-012023-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2023-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2023-12-31 C008999 Midnight: rpl ABS J0348 & Steel Busferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2022-Part 3-UG to Repl O'Head Hoy Rferc:ElectricUtilityMember 2023-12-31 C008999 PWTHR IT Systemsferc:ElectricUtilityMember 2023-12-31 C008999 CANTON ROAD/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 Income Taxes 2023-01-012023-12-31 C008999 Franchise - City, Local Tax, , 2023-12-31 C008999 GS-299 MS Gen. Lghtg & Pwr Muni. Service 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Digital LIHEAP 2023-12-31 C008999 Mississippi Power & Light Co.ferc:SubsidiaryCompanySubheadingMember 2023-01-012023-12-31 C008999 EML: 230-13.8kV | 67MVA Incrementalferc:ElectricUtilityMember 2023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-2169 2023-01-012023-12-31 C008999 BOVINA, Distribution, Unattended 2023-01-012023-12-31 C008999 SHELBY SS, Transmission, Unattended 2023-01-012023-12-31 C008999 Entergy Power & Light Company 2023-12-31 C008999 MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan 2023-12-31 C008999 COLDWATER, Distribution, Unattended 2023-12-31 C008999 GREENVILLE/EAST, Distribution, Unattended 2023-01-012023-12-31 C008999 LELAND, Distribution, Unattended 2023-12-31 C008999 BATESVILLE, SIX MILE LAKE 230 kV - [52301], Wood H-Frame, 2023-01-012023-12-31 C008999 Franklin-GGNS 500Kv Phase Swaferc:ElectricUtilityMember 2023-12-31 C008999 ferc:NextTwelveMonthsMemberferc:NitrogenOxideMember 2023-01-012023-12-31 C008999 RFL-16 Rural Flood Lighting 2023-01-012023-12-31 C008999 LAKEOVER, REX BROWN (EAST) 230 - [6184], Steel Tower, 1272 ACSR 2023-01-012023-12-31 C008999 WALLS, Distribution, Unattended 2023-01-012023-12-31 C008999 SHELBY, Distribution, Unattended 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER15-358 2023-01-012023-12-31 C008999 Accr Prx Code-Dist Cap EML 2023-01-012023-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2023-12-31 C008999 STRINGTOWN, Distribution, Unattended 2023-12-31 C008999 GRENADA, Distribution, Unattended 2023-12-31 C008999 Baxter Wilson install new station s 2023-01-012023-12-31 C008999 Beech Grove: Scope, Design, Engineeferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 See Footnote Detail 2023-01-012023-12-31 C008999 ferc:OtherPropertyTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MS FEEDER INVESTMENT, 2024, CLINTON 2023-01-012023-12-31 C008999 FootnoteDataAbstract 2023-01-012023-12-31 C008999 ferc:UnemploymentTaxMember 2022-12-31 C008999 C6ML300079: Norrell - Tinnin Rd 230ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:DistributionSubstationMember 2023-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:StateTaxMember 2023-01-012023-12-31 C008999 VICKSBURG/EAST, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:Quarter1Member Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 Estimated Consolidated Income Tax Allocated - See Footnote Detail 2023-01-012023-12-31 C008999 VICKSBURG/WEST, Distribution, Unattended 2023-01-012023-12-31 C008999 JONESTOWN, Distribution, Unattended 2023-12-31 C008999 10%ferc:ElectricUtilityMember 2022-12-31 C008999 Magee: Replace breaker J5820 & J582 2023-01-012023-12-31 C008999 CO1 LTSA Capitalization- CT-301 2023-01-012023-12-31 C008999 Grenada Ind-Grenada S 115kV Cut-Inferc:ElectricUtilityMember 2023-12-31 C008999 STREET LIGHT TECHNICAL DESIGN-MCCOMferc:ElectricUtilityMember 2023-12-31 C008999 EMI: Camlin Pilot (Grenada S)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FLORA, Distribution, Unattended 2023-01-012023-12-31 C008999 2.85% Series 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Catlett Road - Expand 230kV Substat 2023-12-31 C008999 Land and Land Rights Under $250,000ferc:LandAndRightsMember 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:TwoYearsMember 2023-12-31 C008999 Other Property Under $250,000 2023-01-012023-12-31 C008999 ferc:UnemploymentTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Downtown Jackson - Replace 1500 KVA 2023-01-012023-12-31 C008999 HORN LAKE, Transmission, Unattended 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Gerald Andrus) 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-827 2023-01-012023-12-31 C008999 C6ML300112: Pelahatchie - Rankin 11ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Federal Income Tax, Federal Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1777 2023-01-012023-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2022-12-31 C008999 Total 115kV, , , 2023-01-012023-12-31 C008999 Lakeover-Hinds 230kV CAP 2023-01-012023-12-31 C008999 MPSC Docket No. 2018-UN-205 - 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Amended Tariff, Docket No. ER16-2199 2023-01-012023-12-31 C008999 HL-21 Public Highway & Park Lighting 2023-01-012023-12-31 C008999 Miscellaneous 2023-01-012023-12-31 C008999 NESBIT, Distribution, Unattended 2023-12-31 C008999 , , , 2023-01-012023-12-31 C008999 HARPER, Transmission, Unattended 2023-12-31 C008999 P2R Upgrade 2022-23ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OperatingUtilityMember 2023-12-31 C008999 Contract Rates 2023-01-012023-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Greenville-SE Greenville115kV LnUpr 2023-12-31 C008999 B(4), Transmission University Research 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2022-12-31 C008999 KOSCIUSKO, Distribution, Unattended 2023-01-012023-12-31 C008999 C6ML300106: Rolling Fork - Onward 1 2023-01-012023-12-31 C008999 Other 2023-01-012023-12-31 C008999 ferc:OtherUseTaxMember 2022-12-31 C008999 EML: Camlin Pilot - 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Service 2023-01-012023-12-31 C008999 ferc:NovemberMember 0 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Spencer Potash: Replace Main Breake 2023-12-31 C008999 Liberty Development 2022-12-31 C008999 EML: 115-13.8kV | 50MVA LTC 2023-01-012023-12-31 C008999 TUNICA, TWINKLETOWN 230 - [5525], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER22-2562 2023-01-012023-12-31 C008999 ferc:IncomeTaxMember 2023-12-31 C008999 COMO, Distribution, Unattended 2023-12-31 C008999 Grant Writing Costs - EML 2023-01-012023-12-31 C008999 *** DESIGN HOLD*** SOUTHAVEN - CITY 2023-01-012023-12-31 C008999 Byhalia 230-13.8kV Phase 1 Expand L 2023-01-012023-12-31 C008999 EML: 13.8kV | 2.667MVA Spare Regs 2023-01-012023-12-31 C008999 Electric Deferred Fuel Over-Recovery 2023-12-31 C008999 2023-Madison-Replace UG along 463 iferc:ElectricUtilityMember 2023-12-31 C008999 GLOSTER, Distribution, Unattended 2023-01-012023-12-31 C008999 Winona: Replace Storm Damagesferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Electric Line Justificantion Extension 2023-12-31 C008999 Qualified Pension funded status 2022-12-31 C008999 ferc:AdValoremTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FLOWERS, Distribution, Unattended 2023-12-31 C008999 Other working capital 2023-01-012023-12-31 C008999 PGen Smart Procedures 2023-01-012023-12-31 C008999 SNOWDEN PARK, Distribution, Unattended 2023-12-31 C008999 ferc:OtherTaxesAndFeesMember 2023-12-31 C008999 Land and Land Rights Under $250,000ferc:LandAndRightsMember 2023-12-31 C008999 ferc:AprilMember 0 2023-01-012023-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2023-01-012023-12-31 C008999 BELZONI, Distribution, Unattended 2023-01-012023-12-31 C008999 LAKEOVER EHV, Transmission, Unattended 2023-12-31 C008999 LEXINGTON, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:JuneMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 ferc:Quarter1Member 0 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1449 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMemberferc:OtherProductionPlantMember 2023-01-012023-12-31 C008999 Attala 2023-01-012023-12-31 C008999 Mendenhall: Replace transformer J49 2023-01-012023-12-31 C008999 5.0% Series 2023-01-012023-12-31 C008999 C6ML300090: Copiah SS - Hazlehurst 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Gerald Andrus)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Small Residential Generation , OS , 2023-01-012023-12-31 C008999 Receipt from storm reserve escrow account 2023-01-012023-12-31 C008999 Drew: Add circuit switchers, replacferc:ElectricUtilityMember 2023-12-31 C008999 GM-Vicksburg SE Guild 5F03-N7, N8, 2023-01-012023-12-31 C008999 PICKENS, Distribution, Unattended 2023-12-31 C008999 GM-Vicksburg SE Guild 5F02-N7, N8,ferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherUseTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 GREENVILLE/INDUSTRIAL, Distribution, Unattended 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Grenada S) 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022 2022-12-31 C008999 Midcontinent Independent System Operator Inc 2023-01-012023-12-31 C008999 Mississippi Power & Light Company 2023-01-012023-12-31 C008999 SOUTHAVEN - CITY WIDE LED CONVERSIOferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 SILVER CREEK, Distribution, Unattended 2023-01-012023-12-31 C008999 UFL-16 Urban Flood Lighting 2023-01-012023-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2023-01-012023-12-31 C008999 GS-299 MS Gen. 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Amort pd Aug 2022 thru June 2023 2023-01-012023-12-31 C008999 UTICA, Distribution, Unattended 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER19-652 2023-01-012023-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 eMobility Digital Tool WOferc:ElectricUtilityMember 2023-12-31 C008999 ferc:NitrogenOxideMemberferc:AfterThreeYearsMember 2023-12-31 C008999 SE21-002V Senatobia Scopingferc:ElectricUtilityMember 2023-12-31 C008999 EML: Camlin Pilot - Baxter Wilsonferc:ElectricUtilityMember 2023-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2023-12-31 C008999 Natchez S:  Replace J0855 XFMRferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2022-Grenada-S Archie Jackson Rd-Miferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other 2023-01-012023-12-31 C008999 ferc:StateTaxMember 2022-12-31 C008999 Long-Term Incentive Plan 2023-01-012023-12-31 C008999 MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb) 2023-01-012023-12-31 C008999 Other Property Under $250,000ferc:OtherPropertyMember 2023-12-31 C008999 MPSC Docket No. 2009-UN-388 - Attorney General Litigation 2022-12-31 C008999 Round Lake S.S.-J1294-Intrcntferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Pine Tree - 1Y05 & 1Y01 Tieferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 NATCHEZ/SOUTH, Distribution, Unattended 2023-01-012023-12-31 C008999 eMobility Digital Tool WOferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 REX BROWN 115 SWYD, Distribution, Unattended 2023-01-012023-12-31 C008999 Other expenses incurred in connection with MISO and other transmission related FERC dockets 2023-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2023-01-012023-06-30 C008999 Unbilled Revenue Accrual (Phase 2) 2023-01-012023-12-31 C008999 OTHER TRANSMISSION LINES PLANTferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 139 months beg April 2023 2023-12-31 C008999 FREEPORT, HORN LAKE 230 - [5942], Concrete Pole, 954 ACSR 2023-01-012023-12-31 C008999 ferc:NitrogenOxideMemberferc:TwoYearsMember 2023-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2023-12-31 C008999 Unbilled Revenue Accrual (Phase 2)ferc:ElectricUtilityMember 2023-12-31 C008999 Mark-to-Market 2022-12-31 C008999 MCCOMB, Distribution, Unattended 2023-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER14-649 2023-01-012023-12-31 C008999 WOLF CREEK, Transmission, Unattended 2023-01-012023-12-31 C008999 JACKSON/EAST, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:ExciseTaxMember 2022-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2022-12-31 C008999 SE21-002V Senatobia Scopingferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:NextTwelveMonthsMember 2023-01-012023-12-31 C008999 See Footnoteferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherFederalTaxMember 2023-12-31 C008999 WOLF CREEK, Transmission, Unattended 2023-12-31 C008999 Charleston: Install Transformer andferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FLOWOOD, Distribution, Unattended 2023-01-012023-12-31 C008999 3.1% Series 2023-12-31 C008999 LULA, Distribution, Unattended 2023-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2023-01-012023-12-31 C008999 MPSC Docket No. 2014-UN-132 - EML Formula Rate Plan 2023-01-012023-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2022-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2023-01-012023-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2023-12-31 C008999 CHOCTAW, Transmission, Unattended 2023-12-31 C008999 2023-01-012023-06-30 C008999 Executive Vice President and Chief Financial Officer 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F03-N7, N8,ferc:ElectricUtilityMember 2023-12-31 C008999 Pine Tree Substation T&D D-Scopingferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 SPENCER POTASH, Distribution, Unattended 2023-12-31 C008999 Other 2022-01-012022-12-31 C008999 Choctaw Gas 2023-01-012023-12-31 C008999 FONDREN/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 GREENBROOK, Distribution, Unattended 2023-12-31 C008999 LULA, Distribution, Unattended 2023-01-012023-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2023-01-012023-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2023-12-31 C008999 CO1 LTSA Capitalization CT 101ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Downtown Jackson - Replace 1500 KVAferc:ElectricUtilityMember 2023-12-31 C008999 Income Taxes 2023-01-012023-12-31 C008999 WOODVILLE [MS], Distribution, Unattended 2023-01-012023-12-31 C008999 Other expenses incurred in connection with MISO and other transmission related FERC dockets 2023-01-012023-12-31 C008999 ferc:IncomeTaxMember 2023-01-012023-12-31 C008999 C6ML300085: North Greenville - Striferc:ElectricUtilityMember 2023-12-31 C008999 WOLF CREEK, MCADAMS 500 - [6960], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 ferc:FederalTaxMember 2023-12-31 C008999 Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620 2023-12-31 C008999 UPIC-Jackson-Livingston Rd-VLP, LLCferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Clearing Accounts (Account 184) 2023-01-012023-12-31 C008999 EML: 115-13.8kV | 50MVA LTCferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:FranchiseTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CENTREVILLE, Distribution, Unattended 2023-12-31 C008999 ferc:SeveranceTaxMember 2023-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2023-12-31 C008999 State Income Tax, State Tax, , 2022-12-31 C008999 T&D - Madison Substation - Feeder-M 2023-01-012023-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2023-01-012023-12-31 C008999 MCCOMB, Distribution, Unattended 2023-01-012023-12-31 C008999 OTHER PRODUCTION PLANTferc:ElectricUtilityMember 2023-12-31 C008999 Pelahatchie: Replace capacitor bankferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 BRANDON, Distribution, Unattended 2023-01-012023-12-31 C008999 Round Lake S.S.-J1294-Intrcntferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER23-2707 2023-01-012023-12-31 C008999 4.9% Series 2023-01-012023-12-31 C008999 MS Sunflower Partnership, LLC 2023-12-31 C008999 ferc:DistributionPlantMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER22-489 2023-01-012023-12-31 C008999 WHITFIELD, Distribution, Unattended 2023-12-31 C008999 GREENVILLE/NORTH, Distribution, Unattended 2023-12-31 C008999 Stores Expense Undistributed (Account 163) 2023-01-012023-12-31 C008999 Durant: Add circuit switchers, replferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 C6ML300089: James Rd - Hazlehurst 1ferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherTaxesAndFeesMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER22-2202 2023-01-012023-12-31 C008999 Chief Executive Officer of Entergy Corporation 2023-01-012023-12-31 C008999 10%ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CARTHAGE (MS), Distribution, Unattended 2023-12-31 C008999 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2023-01-012023-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2023-12-31 C008999 Madison 115kV Second Xfmr T&D Projeferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Video Management Solution Projectferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember Allowances Used 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER22-2332 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022 2023-12-31 C008999 ferc:OtherFederalTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 C6ML300079: Norrell - Tinnin Rd 230 2023-01-012023-12-31 C008999 Relocate Facilities W Capitol Stferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 HERNANDO, Distribution, Unattended 2023-12-31 C008999 ferc:IncomeTaxMember 2022-12-31 C008999 Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1, Docket No. ER13-948 2023-01-012023-12-31 C008999 ferc:OtherUseTaxMember 2023-12-31 C008999 WEBB, Distribution, Unattended 2023-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2023-12-31 C008999 ferc:ElectricUtilityMember Dundee 115kV SS Solar J1440 Scoping 2023-01-012023-12-31 C008999 Round Lake - Indianola Remote Endferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OtherFederalTaxMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Vicksburg S:  Replace XFMR 2023-12-31 C008999 RFL-16 Rural Flood Lighting 2023-01-012023-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2023-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2023-01-012023-12-31 C008999 JACKSON/SOUTH, Transmission, Unattended 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:TwoYearsMember 2023-01-012023-12-31 C008999 Non-Qualified Pension funded status 2022-12-31 C008999 Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020 2023-01-012023-12-31 C008999 2020 Planning CL20-005V New Build Nferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:DecemberMember 0 2023-01-012023-12-31 C008999 SARDIS, Distribution, Unattended 2023-01-012023-12-31 C008999 CVO - Cleveland SC Roofing (Storm) 2023-01-012023-12-31 C008999 RAY BRASWELL EHV, Transmission, Unattended 2023-12-31 C008999 New Endris 230kV Swtiching Station 2023-01-012023-12-31 C008999 Non-Qualified Pension funded status 2023-01-012023-12-31 C008999 3.25% Series 2023-01-012023-12-31 C008999 2020 - SOUTHAVEN - PLUM POINT - CHUferc:ElectricUtilityMember 2023-12-31 C008999 New Endris 230kV Swtiching Stationferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OperatingUtilityMember 2022-12-31 C008999 FAYETTE, Distribution, Unattended 2023-01-012023-12-31 C008999 Round Lake S.S.-J1294-Intrcnt 2023-01-012023-12-31 C008999 SIX MILE LAKE, MOON LAKE SS 230 kV - [52347], Wood H-Frame, 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Grenada S)ferc:ElectricUtilityMember 2023-12-31 C008999 CLEVELAND/SOUTH, Distribution, Unattended 2023-01-012023-12-31 C008999 HAZLEHURST, Distribution, Unattended 2023-12-31 C008999 Clinton KAST Center Training Equipm 2023-01-012023-12-31 C008999 GRENADA, Distribution, Unattended 2023-01-012023-12-31 C008999 GS-299 General Lighting and Power 2023-01-012023-12-31 C008999 Other 2023-12-31 C008999 CL21-002V Clinton Tinnin MT02 Longferc:ElectricUtilityMember 2023-12-31 C008999 BOVINA, Distribution, Unattended 2023-12-31 C008999 GEORGETOWN [MS], Distribution, Unattended 2023-01-012023-12-31 C008999 EML: Camlin Mon S Grenada AT1 2023-01-012023-12-31 C008999 Term Loan 2023-12-31 C008999 C6ML300092: Canton - Pickens 230kVferc:ElectricUtilityMember 2023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2023-01-012023-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2023-12-31 C008999 IBM MRO IO Entergy Interfaceferc:ElectricUtilityMember 2023-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1 2023-01-012023-12-31 C008999 CANTON ROAD/JACKSON, Distribution, Unattended 2023-12-31 C008999 C6ML300113: Flowers - Tinsley 115kVferc:ElectricUtilityMember 2023-12-31 C008999 C6ML300087: North Greenville - Stri 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember IEDMS/ESNET Software Upgrade 2023-12-31 C008999 Oil Baxter Wilson 2023-01-012023-12-31 C008999 RS-39C Residential Service 2023-01-012023-12-31 C008999 FLOWOOD-KELLI FOSTER-LES MAISON PHA 2023-01-012023-12-31 C008999 VICKSBURG/OPENWOOD, Distribution, Unattended 2023-12-31 C008999 C6ML300112: Pelahatchie - Rankin 11 2023-01-012023-12-31 C008999 2022-Part 3-UG to Repl O'Head Hoy Rferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Round Lake - Indianola Remote End 2023-01-012023-12-31 C008999 FLOWOOD-KELLI FOSTER-LES MAISON PHAferc:ElectricUtilityMember 2023-12-31 C008999 EMI: Camlin Pilot (Ray Braswell)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2022-12-31 C008999 EMI: Camlin Pilot (Freeport)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis 2023-12-31 C008999 Terra Miss Nitrogen , OS , 2023-01-012023-12-31 C008999 SOUTH JACKSON, RANKIN 230 - [7350], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 NATCHEZ SWYD, Transmission, Unattended 2023-12-31 C008999 Other Post Retirement Plans 2023-12-31 C008999 MPSC Docket No. 2009-UN-388 - Attorney General Litigation 2023-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2023-12-31 C008999 C6ML300116: Delta SWYD - Cleveland/ 2023-01-012023-12-31 C008999 SW-Facilities Ratings WS-NERC Repferc:ElectricUtilityMember 2023-12-31 C008999 B(1), EPRI (3) 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 , , , 2023-12-31 C008999 Greenville TCEPA - Arcola 115kV CAP 2023-01-012023-12-31 C008999 ferc:OtherTaxesAndFeesMember 2022-12-31 C008999 Federal Income Tax, Federal Tax, , 2023-01-012023-12-31 C008999 ferc:Quarter2Member Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 HORN LAKE, ALLEN S 161 - [5960], Steel Pole, 954 ACSS 2023-01-012023-12-31 C008999 Federal Uemployment Tax, Federal Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Baird, Baird Rd, Mathew Miller Irriferc:ElectricUtilityMember 2023-12-31 C008999 Changes in money pool receivable - net 2023-01-012023-12-31 C008999 Grenada Industrial 115kV Substationferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:StateTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OtherUtilityOrNonutilityMember Mississippi ITC 2022-12-31 C008999 Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620 2022-12-31 C008999 UPIC-Jackson-Livingston Rd-VLP, LLC 2023-01-012023-12-31 C008999 Clinton KAST Center Training Equipmferc:ElectricUtilityMember 2023-12-31 C008999 RK20-010V Magee 7N01 Scopingferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OctoberMember 0 2023-01-012023-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2023-01-012023-12-31 C008999 5% surcharge on regulated billings to non-regulated affiliates 2023-01-012023-12-31 C008999 Winona: Replace Storm Damagesferc:ElectricUtilityMember 2023-12-31 C008999 Baxter Wilson 2023-12-31 C008999 MISO Sch 2 Reactive 2023-01-012023-03-31 C008999 INDIANOLA, TILLATOBA 230 - [6020], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 CLARKSDALE, Distribution, Unattended 2023-12-31 C008999 MP-22 Municipal Pumping Power Service 2023-01-012023-12-31 C008999 CO1 - Choctaw Emergency Generatorferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Change in credit borrowings - net 2023-01-012023-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-Inferc:ElectricUtilityMember 2023-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2023-01-012023-12-31 C008999 MS FEEDER INVESTMENT, 2023, CLINTONferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Digital LIHEAP 2023-01-012023-12-31 C008999 LIBERTY, Distribution, Unattended 2023-12-31 C008999 Webb 115kV-J908 Intercon AddBrks NU 2023-01-012023-12-31 C008999 Greenville TCEPA - Arcola 115kV CAPferc:ElectricUtilityMember 2023-12-31 C008999 CENTREVILLE, Distribution, Unattended 2023-01-012023-12-31 C008999 Getwell-Twinkletown 230kV Cut-Inferc:ElectricUtilityMember 2023-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2023-12-31 C008999 Church Rd-Getwell 230kV T-Line 2023-01-012023-12-31 C008999 Regulatory Commission, Other Taxes, , 2022-12-31 C008999 Chairman of the Board of Entergy Corporation (2) 2023-01-012023-12-31 C008999 SIX MILE LAKE, Transmission, Unattended 2023-12-31 C008999 Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt 2022-01-012022-12-31 C008999 MS FEEDER INVESTMENT, 2023, UTICA,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Federal Income Tax, Federal Tax, , 2022-12-31 C008999 Virliila - New 230kV Substation 2023-01-012023-12-31 C008999 CRM Expansionferc:ElectricUtilityMember 2023-12-31 C008999 Section 263A research - tax services 2023-01-012023-12-31 C008999 SENATOBIA, Distribution, Unattended 2023-01-012023-12-31 C008999 2022-Part 2-UG to Repl O'head Hoy Rferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Tillatoba: Replace Breaker J2520 & 2023-01-012023-12-31 C008999 Indianola - Tillatoba 230kV CAP 2023-01-012023-12-31 C008999 MORTON, Distribution, Unattended 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F03-R8 partferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Webb115kV-J908 IntercnAddBrkrs-TOIFferc:ElectricUtilityMember 2023-12-31 C008999 ferc:ReactiveSupplyAndVoltageMember 2023-01-012023-12-31 C008999 CL21-002V Clinton Tinnin MT02 Longferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Entergy Mississippi, LLCferc:Quarter3Member 2023-01-012023-12-31 C008999 ScheduleElectricPropertyLeasedToOthersAbstract 2023-01-012023-12-31 C008999 WOLF CREEK, FRENCH CAMP 500 - 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2023ferc:ElectricUtilityMember 2023-12-31 C008999 ferc:PayrollTaxMember 2023-12-31 C008999 CATLETT, Distribution, Unattended 2023-12-31 C008999 Indianola: Replace Control House &ferc:ElectricUtilityMember 2023-12-31 C008999 GREENVILLE/EAST, Distribution, Unattended 2023-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 SPO EML SunflowerTaxEquityPartneshp 2023-01-012023-12-31 C008999 TUNICA, Distribution, Unattended 2023-01-012023-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2023-12-31 C008999 B(1), EPRI dues 2023-01-012023-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55 2023-01-012023-12-31 C008999 CRM Expansionferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FC21M053 - FOCUS - FA05 - 55F0575ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 WHITFIELD, Distribution, Unattended 2023-01-012023-12-31 C008999 7% 2023-01-012023-12-31 C008999 ferc:OtherPropertyTaxMember 2022-12-31 C008999 ferc:RealEstateTaxMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Vicksburg S:  Replace XFMR 2023-01-012023-12-31 C008999 MISO Sch 2 Reactive 2023-01-012023-09-30 C008999 EML: 115-13.8kV | 20MVA LTC 2023-01-012023-12-31 C008999 RIDGELAND, Distribution, Unattended 2023-12-31 C008999 Midcontinent ISO, Inc., OS, 2023-01-012023-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2022-12-31 C008999 Vice President and General Tax Counsel 2023-01-012023-12-31 C008999 CVO - 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Baseline Tariff, Docket No. ER13-1508 2023-01-012023-12-31 C008999 ferc:AdValoremTaxMember 2023-12-31 C008999 2021-12-31 C008999 Pine Tree - 1Y05 I-55 Crossingferc:ElectricUtilityMember 2023-12-31 C008999 Cleveland South: Install circuit swferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ROBINSON ROAD/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 P2R Upgrade 2022-23ferc:ElectricUtilityMember 2023-12-31 C008999 Jackson South: Replace 230kV bus diferc:ElectricUtilityMember 2023-12-31 C008999 FLORENCE, Distribution, Unattended 2023-12-31 C008999 AIRPORT/JACKSON, Distribution, Unattended 2023-12-31 C008999 INVERNESS, Distribution, Unattended 2023-12-31 C008999 3.1% Series 2023-01-012023-12-31 C008999 Delta Steam Replace Capacitor Bank 2023-01-012023-12-31 C008999 UPIC-HORN LAKE-WILLOW OAK DR-WILLOWferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other expenses incurred in connection with various filings before the MPSC 2023-12-31 C008999 ScheduleExtraordinaryPropertyLossesAbstract 2023-01-012023-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2023-12-31 C008999 MCADAMS, PICKENS 230 - [6416], Wood H-Frame, 954 ACSR 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember Compliance Deduction 2023-01-012023-12-31 C008999 BRICKYARD, Distribution, Unattended 2023-01-012023-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2023-01-012023-12-31 C008999 Relocate Facilities W Capitol St 2023-01-012023-12-31 C008999 LEXINGTON, Distribution, Unattended 2023-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 - Amort pd Aug 2022 thru June 2023 2022-12-31 C008999 ferc:ExciseTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Normal and Surtax @ 21% 2023-01-012023-12-31 C008999 MOON LAKE SS, Transmission, Unattended 2023-12-31 C008999 Distribution Resiliency Plan 2023-01-012023-12-31 C008999 Grenada Industrial 115kV Substation 2023-01-012023-12-31 C008999 CARTHAGE-CITY OF CARTHAGE LED CONVEferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 State Income Tax, State Tax, , 2023-01-012023-12-31 C008999 LED-2 LED Street and Area  Lighting 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember UNDISTRIBUTED OVERHEADS: 2023-01-012023-12-31 C008999 Receipts & Sales, Other State Tax, , 2022-12-31 C008999 4.52% Series 2023-12-31 C008999 ELLIOTT, Distribution, Unattended 2023-01-012023-12-31 C008999 MIDNIGHT, Distribution, Unattended 2023-01-012023-12-31 C008999 3% 2023-01-012023-12-31 C008999 STREET LIGHT TECHNICAL DESIGN-MCCOMferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other expenses incurred in connection with various filings before the FERC 2023-12-31 C008999 MCADAMS, ATTALA 230 - [6415], Steel Tower, 1272 ACSR 2023-01-012023-12-31 C008999 SOUTHAVEN - CITY WIDE LED CONVERSIOferc:ElectricUtilityMember 2023-12-31 C008999 DURANT, Distribution, Unattended 2023-12-31 C008999 Executive Vice President and Chief Operating Officer of Entergy Corporation 2023-01-012023-12-31 C008999 OTHER TRANSMISSION & DISTRIBUTION SUBSferc:ElectricUtilityMember 2023-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2023-12-31 C008999 2022-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2023-01-012023-03-31 C008999 GRENADA/SOUTH, Distribution, Unattended 2023-12-31 C008999 MPSC Docket No. 2008-UN-381 - Power Management Rider Expense 2023-12-31 C008999 ELTON RD, Distribution, Unattended 2023-01-012023-12-31 C008999 Getwell-Twinkletown 230kV Cut-In 2023-01-012023-12-31 C008999 Gas Baxter Wilson 2023-01-012023-12-31 C008999 ferc:FuelTaxMember 2022-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2023-12-31 C008999 MINTER CITY SS, Transmission, Unattended 2023-12-31 C008999 Increases (Decreases) in Other Paid-In Capital 2023-01-012023-12-31 C008999 DESOTO, Distribution, Unattended 2023-12-31 C008999 ferc:ElectricUtilityMember 2023-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2023-12-31 C008999 2021-GRENADA-ENID 2B01-MDOT BRIDGE 2023-01-012023-12-31 C008999 EML: 13.8kV | 2.667MVA Spare Regsferc:ElectricUtilityMember 2023-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2022-Grenada-S Archie Jackson Rd-Miferc:ElectricUtilityMember 2023-12-31 C008999 FREEPORT, Transmission, Unattended 2023-12-31 C008999 Indianola - 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CITYferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205 2022-12-31 C008999 EML - Penton Solar 2023-01-012023-12-31 C008999 MILL STREET, Distribution, Unattended 2023-01-012023-12-31 C008999 CF Industries Nitrogen, LLC , OS , 2023-01-012023-12-31 C008999 MAGEE, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:IncomeTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 ROXIE, Distribution, Unattended 2023-12-31 C008999 Lake Cormorant-Saint Brigid Subdiviferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MAGEE, Distribution, Unattended 2023-12-31 C008999 MS FEEDER INVESTMENT, 2023, CLINTONferc:ElectricUtilityMember 2023-12-31 C008999 GRAND GULF TRANSMISSION, Transmission, Unattended 2023-01-012023-12-31 C008999 Round Lake - Indianola Remote Endferc:ElectricUtilityMember 2023-12-31 C008999 EDWARDS, Distribution, Unattended 2023-01-012023-12-31 C008999 Madison 115kV Second Xfmr T&D Proje 2023-01-012023-12-31 C008999 ferc:NextTwelveMonthsMemberferc:NitrogenOxideMember 2023-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MPSC Docket No. 2008-UN-381 - Power Management Rider Expense 2023-01-012023-12-31 C008999 PLUM POINT, Distribution, Unattended 2023-01-012023-12-31 C008999 NATCHEZ/SOUTH, Distribution, Unattended 2023-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2023-01-012023-12-31 C008999 OTHER DISTRIBUTION LINES PLANTferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Revolving Credit Facility 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember PGen Smart Procedures 2023-12-31 C008999 Tillatoba-Grenada Ind 115kV Cut-Inferc:ElectricUtilityMember 2023-12-31 C008999 2022 MISO Predictive Analytics 2023-01-012023-12-31 C008999 Choctaw 2023-12-31 C008999 Leland: Replace breaker 3G05 and adferc:ElectricUtilityMember 2023-12-31 C008999 FERNWOOD, Distribution, Unattended 2023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2023-01-012023-12-31 C008999 2023-01-012023-09-30 C008999 Jackson South: Replace 230kV bus diferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Liberty Development 2023-12-31 C008999 RANKIN, Transmission, Unattended 2023-12-31 C008999 ferc:OtherLicenseAndFeesTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 PRELIMINARY SURVEY & INVTG CHferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 ferc:OtherTaxMember 2023-12-31 C008999 Video Management Solution Projectferc:ElectricUtilityMember 2023-12-31 C008999 JACKSON/TREATMENT PLANT, Distribution, Unattended 2023-01-012023-12-31 C008999 Increases (Decreases) from Sales of Donations Received from Stockholders 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Ray Braswell)ferc:ElectricUtilityMember 2023-12-31 C008999 3.85% Series 1 2023-01-012023-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2023-12-31 C008999 ferc:SeptemberMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Ray Braswell) 2023-01-012023-12-31 C008999 C6ML300116: Delta SWYD - 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Hazlehurst 1ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022 2022-12-31 C008999 JOHNS MANVILLE, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:NitrogenOxideMemberferc:TwoYearsMember 2023-01-012023-12-31 C008999 B(4), SERC (1) 2023-01-012023-12-31 C008999 ferc:PenaltyTaxMember 2023-12-31 C008999 LED-2 LED Street and Area  Lighting 2023-01-012023-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2023-01-012023-12-31 C008999 Winona: Replace Storm Damages 2023-01-012023-12-31 C008999 B(4), SERC (2) 2023-01-012023-12-31 C008999 GRENADA/SOUTH, Distribution, Unattended 2023-01-012023-12-31 C008999 State Use Tax, Sales And Use Tax, , 2022-12-31 C008999 EMI New Nuclear, LLC 2023-12-31 C008999 ferc:PropertyTaxMember 2023-01-012023-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2023-01-012023-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2023-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2023-01-012023-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2023-12-31 C008999 QF-18 2023-01-012023-12-31 C008999 GREENVILLE/INDUSTRIAL, Distribution, Unattended 2023-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2022-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2023-12-31 C008999 C6ML300043: Horn Lake - Greenbrookferc:ElectricUtilityMember 2023-12-31 C008999 ferc:NitrogenOxideMember 2023-12-31 C008999 Energy Efficiency Rider Under-Recovery 2023-12-31 C008999 Electric Deferred Fuel Over-Recovery 2023-01-012023-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2023-01-012023-12-31 C008999 RS-39C Residential Service 2023-01-012023-12-31 C008999 LAKEOVER, LUCKNEY 230 - [2311], Steel Tower, 1272 ACSR 2023-01-012023-12-31 C008999 BOZEMAN ROAD, Distribution, Unattended 2023-12-31 C008999 ScheduleEnergyStorageOperationsSmallPlantsAbstract 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember 2022 Woodrow Wilson Relocation 2023-01-012023-12-31 C008999 EML: Camlin Mon S Grenada AT1ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 State Excise Tax, Excise Tax, , 2022-12-31 C008999 SW-Facilities Ratings WS-NERC Rep 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember Purchases/Transfers: 2023-01-012023-12-31 C008999 ferc:PayrollTaxMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMemberferc:SeveranceTaxMember 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F03-R8 partferc:ElectricUtilityMember 2023-12-31 C008999 JACKSON/EAST, Distribution, Unattended 2023-12-31 C008999 Tillatoba-Grenada Ind 115kV Cut-Inferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CATLETT, Distribution, Unattended 2023-01-012023-12-31 C008999 Webb:  Replace J3094 LABferc:ElectricUtilityMember 2023-12-31 C008999 C6ML300113: Flowers - Tinsley 115kV 2023-01-012023-12-31 C008999 Unbilled Revenue Accrual (Phase 2)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER18-1260 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Digital LIHEAP 2023-01-012023-12-31 C008999 ferc:MarchMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 Pine Tree - 1Y05 I-55 Crossing 2023-01-012023-12-31 C008999 BAXTER WILSON, GRAND GULF 500 - [5620], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 EML Public EV Charging Pilot 2023-01-012023-12-31 C008999 BOLTON, Distribution, Unattended 2023-12-31 C008999 MERCHANT ROAD, Transmission, Unattended 2023-12-31 C008999 3.5% Series 2 2023-01-012023-12-31 C008999 3.85% Series 2 2023-12-31 C008999 ROBINSON ROAD/JACKSON, Distribution, Unattended 2023-12-31 C008999 ferc:SeveranceTaxMember 2022-12-31 C008999 2020 - SOUTHAVEN - PLUM POINT - CHU 2023-01-012023-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FAYETTE, Distribution, Unattended 2023-12-31 C008999 SENATOBIA, Distribution, Unattended 2023-12-31 C008999 CATLETT, TINNIN RD 230 - [5112], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 Gerald Andrus 2023-01-012023-12-31 C008999 Greenwood:  Replace XFMR J6825ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 State Income Tax, State Tax, , 2023-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3 2023-01-012023-12-31 C008999 OTHER TRANSMISSION & DISTRIBUTION SUBS 2023-01-012023-12-31 C008999 Franklin-GGNS 500Kv Phase Swaferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Grand Gulf: Replace East & West busferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Federal Excise Tax, Federal Tax, , 2023-01-012023-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2023-12-31 C008999 Independence 2023-01-012023-12-31 C008999 ferc:JuneMember 0 2023-01-012023-12-31 C008999 RANKIN, Distribution, Unattended 2023-01-012023-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2023-01-012023-03-31 C008999 Franchise - City, Local Tax, , 2023-01-012023-12-31 C008999 LUCKNEY, Distribution, Unattended 2023-01-012023-12-31 C008999 EMI New Nuclear, LLC 2022-12-31 C008999 Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 Mississippi ITC 2023-01-012023-12-31 C008999 DSL-16 Directional Security  Lighting 2023-01-012023-12-31 C008999 Greenwood:  Replace XFMR J6825ferc:ElectricUtilityMember 2023-12-31 C008999 Franklin-GGNS 500Kv Phase Swa 2023-01-012023-12-31 C008999 ferc:UnemploymentTaxMember 2023-01-012023-12-31 C008999 Section 263A 2022-12-31 C008999 ferc:NovemberMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 MADISON, Distribution, Unattended 2023-01-012023-12-31 C008999 Midnight: rpl Oil Pump on J0346 2023-01-012023-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2022-12-31 C008999 TERRY, Distribution, Unattended 2023-01-012023-12-31 C008999 RIDGELAND, Distribution, Unattended 2023-01-012023-12-31 C008999 Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt 2023-01-012023-12-31 C008999 Grid Modernization Rider Under-Recovery MPSC Docket No. 2017-UN-198 2023-01-012023-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2023-01-012023-12-31 C008999 ferc:OtherTaxMember 2022-12-31 C008999 FRANKLIN, RAY BRASWELL 500 - [6980], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 B(4), North American Transmission Forum Inc 2023-01-012023-12-31 C008999 RULEVILLE, Distribution, Unattended 2023-12-31 C008999 GERALD ANDRUS SES SWYD, Transmission, Unattended 2023-12-31 C008999 Magee: Replace breaker J5820 & J582ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:SteamProductionPlantMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Derivative Instruments and Hedging Activities 2022-12-31 C008999 Other (provide details in footnote):ferc:GasOtherFacilitiesMember 2023-01-012023-12-31 C008999 MS Sunflower Partnership, LLC 2023-01-012023-12-31 C008999 Other 2022-01-012022-12-31 C008999 LARSON ST/JACKSON, Distribution, Unattended 2023-12-31 C008999 ENID, Distribution, Unattended 2023-12-31 C008999 C-29 Large General Service 2023-01-012023-12-31 C008999 ENID, Distribution, Unattended 2023-01-012023-12-31 C008999 EML: 13.8kV | 1.25MVA Regulator 2023-01-012023-12-31 C008999 2023-Madison-Canton-Fac Relocationferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FC21M053 - FOCUS - FA05 - 55F0575 2023-01-012023-12-31 C008999 2020 Planning CL20-005V New Build N 2023-01-012023-12-31 C008999 KINGSWOOD/JACKSON, Distribution, Unattended 2023-12-31 C008999 Drew: Add circuit switchers, replac 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-1720 2023-01-012023-12-31 C008999 Yazoo City SW St:  Rpl XFMRferc:ElectricUtilityMember 2023-12-31 C008999 2.55% Series 2023-12-31 C008999 ferc:FederalInsuranceTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Greenville-SE Greenville115kV LnUpr 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1472 2023-01-012023-12-31 C008999 Mendenhall: Replace transformer J49ferc:ElectricUtilityMember 2023-12-31 C008999 MENDENHALL, Distribution, Unattended 2023-12-31 C008999 OTHER TRANSMISSION LINES PLANTferc:ElectricUtilityMember 2023-12-31 C008999 ferc:SulfurDioxideMemberferc:ThreeYearsMember 2023-12-31 C008999 GETWELL, Distribution, Unattended 2023-01-012023-12-31 C008999 PICKENS, Transmission, Unattended 2023-12-31 C008999 *** DESIGN HOLD*** SOUTHAVEN - CITYferc:ElectricUtilityMember 2023-12-31 C008999 EML: 13.8kV | 1.25MVA Regulatorferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Mississippi Power & Light Co. 2023-12-31 C008999 Grid Modernization Rider Under-Recovery MPSC Docket No. 2017-UN-198 2023-12-31 C008999 MARKS, Distribution, Unattended 2023-01-012023-12-31 C008999 OTHER DISTRIBUTION LINES PLANT 2023-01-012023-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:ExciseTaxMember 2023-01-012023-12-31 C008999 YAZOO CITY SS, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:AugustMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 SHELBY, Distribution, Unattended 2023-01-012023-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2023-01-012023-12-31 C008999 Other Property Under $250,000ferc:OtherPropertyMember 2023-01-012023-12-31 C008999 2023-Madison-Canton-Fac Relocationferc:ElectricUtilityMember 2023-12-31 C008999 PAL-17 Private Area Lighting 2023-01-012023-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember Compliance Deductionferc:CurrentYearMember 2023-01-012023-12-31 C008999 Common equity distributions paid 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember 2021-GRENADA-ENID 2B01-MDOT BRIDGE 2023-12-31 C008999 Beech Grove: Scope, Design, Enginee 2023-01-012023-12-31 C008999 Pickens: Replace 4 ea. HV Breakersferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Lakeover) 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 135 months beg April 2023 2023-12-31 C008999 NORTHPARK, Transmission, Unattended 2023-12-31 C008999 ferc:FederalInsuranceTaxMember 2023-12-31 C008999 ferc:OtherPropertyTaxMember 2023-01-012023-12-31 C008999 MISO Various Various 2023-01-012023-12-31 C008999 C6ML300089: James Rd - Hazlehurst 1 2023-01-012023-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl) 2023-01-012023-12-31 C008999 ferc:IntangiblePlantMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 HERNANDO, Distribution, Unattended 2023-01-012023-12-31 C008999 VICKSBURG, Distribution, Unattended 2023-12-31 C008999 CHOCTAW, FRENCH CAMP 500 - [5014], Steel Pole, 954 ACSR 2023-01-012023-12-31 C008999 FICA, Federal Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Natchez S:  Replace J0855 XFMR 2023-01-012023-12-31 C008999 IBM MRO IO Entergy Interfaceferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CARTHAGE-CITY OF CARTHAGE LED CONVEferc:ElectricUtilityMember 2023-12-31 C008999 Non-Qualified Pension funded status 2023-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2023-12-31 C008999 FLOWOOD, Distribution, Unattended 2023-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OtherAdValoremTaxMember 2022-12-31 C008999 ferc:RealEstateTaxMember 2022-12-31 C008999 ferc:OtherUtilityMember Other (Specify) 2023-01-012023-12-31 C008999 Jackson Call Ctr Task Chairsferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 B(1), EPRI (1) 2023-01-012023-12-31 C008999 C6ML300118: Onward - Redwood 115kV 2023-01-012023-12-31 C008999 Vicksburg S:  Replace XFMR 2023-01-012023-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2023-01-012023-12-31 C008999 State Income Tax, State Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Total 161kV, , , 2023-01-012023-12-31 C008999 MENDENHALL, Distribution, Unattended 2023-01-012023-12-31 C008999 CO1 - Choctaw Emergency Generatorferc:ElectricUtilityMember 2023-12-31 C008999 SNOWDEN PARK, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:Quarter3Member 0 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1ferc:ElectricUtilityMember 2023-12-31 C008999 ferc:MiscellaneousOtherTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2022 MISO Predictive Analyticsferc:ElectricUtilityMember 2023-12-31 C008999 MADISON, Distribution, Unattended 2023-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2023-01-012023-12-31 C008999 SPENCER POTASH, Distribution, Unattended 2023-01-012023-12-31 C008999 Electric Line Justificantion Extension 2022-12-31 C008999 Jackson Call Ctr Task Chairsferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2023-01-012023-12-31 C008999 RALEIGH, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:FranchiseTaxMember 2023-12-31 C008999 Attala 2023-12-31 C008999 FICA, Federal Tax, , 2023-12-31 C008999 WALLS, Distribution, Unattended 2023-12-31 C008999 RAY BRASWELL, LAKEOVER 500 - [7130], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 Senior Vice President and Chief Accounting Officer 2023-01-012023-12-31 C008999 Miss. Signage Rebranding Costsferc:ElectricUtilityMember 2023-12-31 C008999 Federal Excise Tax, Federal Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 See Footnote Detail 2023-01-012023-12-31 C008999 State Unemployment Tax, Unemployment Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 TILLATOBA, BATESVILLE 230 - [5840], Concrete Pole, 1780 ACSR 2023-01-012023-12-31 C008999 Pelahatchie: Replace capacitor bankferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherAdValoremTaxMember 2023-12-31 C008999 ferc:Quarter4Member 0 2023-01-012023-12-31 C008999 TILLATOBA, Transmission, Unattended 2023-12-31 C008999 ferc:ElectricUtilityMember C6ML300045: Canton - S. Canton 230k 2023-01-012023-12-31 C008999 GS-299 General Lighting and Power 2023-01-012023-12-31 C008999 Jackson Call Ctr Task Chairs 2023-01-012023-12-31 C008999 EML: 115-13.8kV | 20MVA LTCferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER22-1602 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER19-747 2023-01-012023-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2023-01-012023-12-31 C008999 NORTHPARK, Distribution, Unattended 2023-01-012023-12-31 C008999 Other Reconciling Items - See footnote detail 2023-01-012023-12-31 C008999 Grenada: Add circuit switchers, repferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CVO - Cleveland SC Roofing (Storm)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Baird, Baird Rd, Mathew Miller Irriferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Crenshaw:  Add Circuit Switcher 2023-01-012023-12-31 C008999 GERALD ANDRUS, INDIANOLA 230 - [5580], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:ThreeYearsMember 2023-01-012023-12-31 C008999 HOY ROAD, Distribution, Unattended 2023-12-31 C008999 Leland: Replace breaker 3G05 and ad 2023-01-012023-12-31 C008999 CO1 LTSA Capitalization CT 101ferc:ElectricUtilityMember 2023-12-31 C008999 OTHER DISTRIBUTION LINES PLANTferc:ElectricUtilityMember 2023-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2023-01-012023-12-31 C008999 RAY BRASWELL, NORREL 230 - [2340], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 JACKSON/NORTHWEST, Distribution, Unattended 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER19-1503 2023-01-012023-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2023-12-31 C008999 EML: 13.8kV | 1.25MVA Regulatorferc:ElectricUtilityMember 2023-12-31 C008999 Federal Excise Tax, Federal Tax, , 2022-12-31 C008999 Mississippi Power & Light Co. 2023-01-012023-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2023-12-31 C008999 Qualified Pension funded status 2023-12-31 C008999 TERRY, Distribution, Unattended 2023-12-31 C008999 VICKSBURG, Distribution, Unattended 2023-01-012023-12-31 C008999 VICKSBURG/SOUTHEAST, Distribution, Unattended 2023-12-31 C008999 ATTALA PLANT, Transmission, Unattended 2023-01-012023-12-31 C008999 ferc:OtherAdValoremTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Accr Prx Code-Dist Cap EMLferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F03-N7, N8,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 NATCHEZ/INDUSTRIAL PARK, Distribution, Unattended 2023-12-31 C008999 Federal Income Tax, Federal Tax, , 2023-12-31 C008999 BROOKHAVEN-HWY 51-CITY OF BROOKHAVE 2023-01-012023-12-31 C008999 NORTHPARK, Distribution, Unattended 2023-12-31 C008999 2020 Planning CL20-005V Rep A1, RREferc:ElectricUtilityMember 2023-12-31 C008999 ferc:ElectricUtilityMember IEDMS/ESNET Software Upgrade 2023-01-012023-12-31 C008999 MEADVILLE, Distribution, Unattended 2023-01-012023-12-31 C008999 PELAHATCHIE - INDUSTRIAL DR - MENASferc:ElectricUtilityMember 2023-12-31 C008999 TYLERTOWN, Distribution, Unattended 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER18-1982 2023-01-012023-12-31 C008999 FOREST HILL/JACKSON, Distribution, Unattended 2023-12-31 C008999 ferc:ElectricUtilityMember Greenville-SE Greenville115kV LnUpr 2023-01-012023-12-31 C008999 ferc:LocalTaxMember 2023-01-012023-12-31 C008999 HLF-7 High Load Factor 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Catlett Road - Expand 230kV Substat 2023-01-012023-12-31 C008999 HOLLANDALE, Distribution, Unattended 2023-01-012023-12-31 C008999 Webb115kV-J908 IntercnAddBrkrs-TOIF 2023-01-012023-12-31 C008999 GALLMAN, Distribution, Unattended 2023-01-012023-12-31 C008999 GLEN ALLAN, Distribution, Unattended 2023-12-31 C008999 Pine Tree - 1Y05 & 1Y01 Tie 2023-01-012023-12-31 C008999 ferc:LocalTaxMember 2022-12-31 C008999 See footnote for schedule details, 2023-01-012023-12-31 C008999 Webb115kV-J908 IntercnAddBrkrs-TOIFferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Total 230kV, , , 2023-01-012023-12-31 C008999 ferc:OtherFederalTaxMember 2022-12-31 C008999 2023-Madison-Canton-Fac Relocation 2023-01-012023-12-31 C008999 BAXTER WILSON, RAY BRASWELL 500 - [6880], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 Legal restrictive convenants agreement 2023-01-012023-12-31 C008999 ferc:FederalTaxMember 2022-12-31 C008999 MEADVILLE, Distribution, Unattended 2023-12-31 C008999 STREET LIGHT TECHNICAL DESIGN-MCCOM 2023-01-012023-12-31 C008999 OTHER PRODUCTION PLANT 2023-01-012023-12-31 C008999 Pickens: Replace 4 ea. HV Breakersferc:ElectricUtilityMember 2023-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022 2023-12-31 C008999 UFL-16 Urban Flood Lighting 2023-01-012023-12-31 C008999 3%ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 BOGALUSA 500, FRANKLIN EHV - [5521], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 SLI JOB-PELAHATCHIE - INDUSTRIAL DR 2023-01-012023-12-31 C008999 JONESTOWN, Distribution, Unattended 2023-01-012023-12-31 C008999 TINNIN RD, GERALD ANDRUS 230 - [52304,52391], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Mannsdale T&D D-Scoping 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1549 2023-01-012023-12-31 C008999 SLI JOB-PELAHATCHIE - INDUSTRIAL DRferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 SLI JOB-- ROBINSONVILLE-1001 SCHULZferc:ElectricUtilityMember 2023-12-31 C008999 C6ML300087: North Greenville - Striferc:ElectricUtilityMember 2023-12-31 C008999 DURANT, Distribution, Unattended 2023-01-012023-12-31 C008999 Belzoni: Install circuit switchers,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2022-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2023-01-012023-12-31 C008999 SL-37 Municipal Street Lighting 2023-01-012023-12-31 C008999 Asset Retirement Obligation - Coal 2023-12-31 C008999 ferc:SalesAndUseTaxMember 2023-01-012023-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2022-12-31 C008999 Byhalia Distribution Scopingferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 CRENSHAW, Distribution, Unattended 2023-12-31 C008999 B(1), EPRI (2) 2023-01-012023-12-31 C008999 ROLLING FORK, Distribution, Unattended 2023-01-012023-12-31 C008999 VICKSBURG/SOUTH, Distribution, Unattended 2023-01-012023-12-31 C008999 Other Deductions (Account 4265)ferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F02-N7, N8,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:PropertyTaxMember 2022-12-31 C008999 Virliila - New 230kV Substationferc:ElectricUtilityMember 2023-12-31 C008999 ferc:SulfurDioxideMemberferc:AfterThreeYearsMember 2023-01-012023-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2023-01-012023-12-31 C008999 FLOWERS, Distribution, Unattended 2023-01-012023-12-31 C008999 Crenshaw:  Add Circuit Switcherferc:ElectricUtilityMember 2023-12-31 C008999 ferc:OtherStateTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Grenada Ind-Grenada S 115kV Cut-In 2023-01-012023-12-31 C008999 Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205 2023-01-012023-12-31 C008999 Group President Utility Operations 2023-01-012023-12-31 C008999 B-34 Intermediate General Service 2023-01-012023-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)ferc:ElectricUtilityMember 2023-12-31 C008999 KOSCIUSKO, Distribution, Unattended 2023-12-31 C008999 GALLMAN, Distribution, Unattended 2023-12-31 C008999 Gerald Andrus Oil 2023-01-012023-12-31 C008999 Pelahatchie - Rankin 115kV CAP 2023-01-012023-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAP 2023-01-012023-12-31 C008999 Pine Tree - 1Y04 - Hwy 51 2023-01-012023-12-31 C008999 EMI: Camlin Pilot Franklin EHV 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2023-12-31 C008999 PICKENS, Transmission, Unattended 2023-01-012023-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember PGen Smart Procedures 2023-01-012023-12-31 C008999 LED-2 LED Street and Area  Lighting 2023-01-012023-12-31 C008999 Non-Expense Accrued Labor 2023-12-31 C008999 GETWELL, BYHALA 230 - [2341], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 TUNICA 230/115 SUB, Transmission, Unattended 2023-12-31 C008999 OTHER TRANSMISSION & DISTRIBUTION SUBSferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 C6ML300116: Delta SWYD - Cleveland/ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2023-12-31 C008999 LED-2 LED Street and Area  Lighting 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 139 months beg April 2023 2023-01-012023-12-31 C008999 GETWELL, Distribution, Unattended 2023-12-31 C008999 Build Pine Tree 230/12.47kV Sub 2023-01-012023-12-31 C008999 2022-Part 1-UG to Repl Ohead Hoy Rd 2023-01-012023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022 2023-01-012023-12-31 C008999 EML - Penton Solarferc:ElectricUtilityMember 2023-12-31 C008999 State Use Tax, Sales And Use Tax, , 2023-12-31 C008999 Tillatoba: Replace Breaker J2520 &ferc:ElectricUtilityMember 2023-12-31 C008999 Increases (Decreases) Due to Miscellaneous Paid-In Capital 2023-01-012023-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2023-01-012023-12-31 C008999 Mississippi Power & Light Company 2023-12-31 C008999 2.85% Series 2023-12-31 C008999 PAL-17 Private Area Lighting 2023-01-012023-12-31 C008999 Mississippi Power & Light Co. 2022-12-31 C008999 Miscellaneous Deferred Debits (Account 186)ferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 GREENWOOD, Distribution, Unattended 2023-12-31 C008999 MPSC Docket No. 2009-UN-388 - Attorney General Litigation 2023-01-012023-12-31 C008999 CANTON, Distribution, Unattended 2023-12-31 C008999 FICA, Federal Tax, , 2023-01-012023-12-31 C008999 Relocate Facilities W Capitol Stferc:ElectricUtilityMember 2023-12-31 C008999 Grant Writing Costs - EMLferc:ElectricUtilityMember 2023-12-31 C008999 Miscellaneous Deferred Debits (Account 186) 2023-01-012023-12-31 C008999 SOUTH CANTON, RAGSDALE 230 LN 1 - [5271], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2023-01-012023-12-31 C008999 PSK405-EML-Grenada Industrial Parkferc:ElectricUtilityMember 2023-12-31 C008999 CLINTON [MS], Distribution, Unattended 2023-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2023-12-31 C008999 SL-37 Municipal Street Lighting 2023-01-012023-12-31 C008999 RITCHIE, TUNICA 230 - [7490], Wood H-Frame, 1947.5 ACSR 2023-01-012023-12-31 C008999 LAKE CASTLE, Distribution, Unattended 2023-01-012023-12-31 C008999 RK20-010V Magee 7N01 Scoping 2023-01-012023-12-31 C008999 Independence 2023-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024 2023-01-012023-12-31 C008999 Grand Gulf: Replace East & West bus 2023-01-012023-12-31 C008999 VALLEY HILL, Transmission, Unattended 2023-01-012023-12-31 C008999 Non-Expense Accrued Labor 2022-12-31 C008999 DELTA SWYD, Transmission, Unattended 2023-12-31 C008999 Liberty Development 2023-01-012023-12-31 C008999 LIBERTY, Distribution, Unattended 2023-01-012023-12-31 C008999 4% 2023-01-012023-12-31 C008999 2020 - SOUTHAVEN - PLUM POINT - CHUferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:RealEstateTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:NitrogenOxideMemberferc:AfterThreeYearsMember 2023-01-012023-12-31 C008999 Energy Efficiency Rider Under-Recovery 2022-12-31 C008999 Pickens: Replace 4 ea. HV Breakers 2023-01-012023-12-31 C008999 Federal Excise Tax, Federal Tax, , 2023-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Catlett Road - Expand 230kV Substat 2023-01-012023-12-31 C008999 Midcontinent ISO, Inc. , OS , 2023-01-012023-12-31 C008999 ferc:FebruaryMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 MP-22 Municipal Pumping Power Service 2023-01-012023-12-31 C008999 Other 2022-01-012022-12-31 C008999 Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022 2023-01-012023-12-31 C008999 GRENADA/SOUTH, Transmission, Unattended 2023-01-012023-12-31 C008999 HAINING ROAD, Distribution, Unattended 2023-01-012023-12-31 C008999 3.5% Series 1 2023-12-31 C008999 Grant Writing Costs - EMLferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER23-1228 2023-01-012023-12-31 C008999 Income Taxes 2023-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2023-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2023-12-31 C008999 EML - Penton Solarferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2023-12-31 C008999 CLARKSDALE, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Mannsdale 230kV Substation 2023-01-012023-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2023-12-31 C008999 EMI: Camlin Pilot Franklin EHVferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 OTHER TRANSMISSION LINES PLANT 2023-01-012023-12-31 C008999 ferc:SalesAndUseTaxMember 2022-12-31 C008999 SE21-002V Senatobia Scoping 2023-01-012023-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2023-12-31 C008999 3.75% Series 2023-12-31 C008999 ferc:ElectricUtilityMember 7% 2023-01-012023-12-31 C008999 EML: 115-13.8kV | 20MVA LTCferc:ElectricUtilityMember 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-215 2023-01-012023-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2023-12-31 C008999 , , , 2022-12-31 C008999 Webb 115kV-J908 Intercon AddBrks NUferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 DSL-16 Directional Security  Lighting 2023-01-012023-12-31 C008999 CHARLESTON, Distribution, Unattended 2023-12-31 C008999 C6ML300106: Rolling Fork - Onward 1ferc:ElectricUtilityMember 2023-12-31 C008999 DELTA SWYD, Transmission, Unattended 2023-01-012023-12-31 C008999 NORTHPARK, Transmission, Unattended 2023-01-012023-12-31 C008999 C6ML300106: Rolling Fork - Onward 1ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:OtherAllocatedTaxMember 2022-12-31 C008999 Jackson Gas Light Company 2023-12-31 C008999 Mississippi Power & Light Co.ferc:UnappriatedUndistributedSubsidiaryEarningsMember 2023-01-012023-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2023-01-012023-12-31 C008999 Grenada: Add circuit switchers, rep 2023-01-012023-12-31 C008999 RANKIN, Distribution, Unattended 2023-12-31 C008999 ferc:MayMember 0 2023-01-012023-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2023-12-31 C008999 FERNWOOD, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember 2023-12-31 C008999 ScheduleCommonUtilityPlantAndExpensesAbstract 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Mannsdale 230kV Substation 2023-12-31 C008999 Church Rd-Getwell 230kV T-Lineferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 State Excise Tax, Excise Tax, , 2023-12-31 C008999 EMI: Camlin Pilot (Gerald Andrus)ferc:ElectricUtilityMember 2023-12-31 C008999 YAZOO CITY MUNICIPAL SS, Transmission, Unattended 2023-01-012023-12-31 C008999 HARPER, Transmission, Unattended 2023-01-012023-12-31 C008999 IEDMS/ESNET Software Upgrade 2023-01-012023-12-31 C008999 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2023-01-012023-12-31 C008999 Wolf Creek - Add 500kV Breaker 2023-01-012023-12-31 C008999 Webb:  Replace J3094 LABferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 UPIC-HORN LAKE-WILLOW OAK DR-WILLOWferc:ElectricUtilityMember 2023-12-31 C008999 Other 2023-01-012023-12-31 C008999 Grenada Ind-Grenada S 115kV Cut-Inferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 B(2), Edison Electric Institute (2) 2023-01-012023-12-31 C008999 ferc:JanuaryMember 0 2023-01-012023-12-31 C008999 KINGSWOOD/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 LAKEOVER EHV, Transmission, Unattended 2023-01-012023-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2023-12-31 C008999 LAKEOVER, YANDELL RD 230 - [2335], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 ROBINSONVILLE, Distribution, Unattended 2023-12-31 C008999 Jackson Gas Light Company 2023-01-012023-12-31 C008999 COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022 2022-12-31 C008999 IBM MRO IO Entergy Interface 2023-01-012023-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2022-12-31 C008999 Income Taxes 2023-12-31 C008999 MIDNIGHT, Distribution, Unattended 2023-12-31 C008999 ferc:OtherStateTaxMember 2023-12-31 C008999 UPIC-Flowood-E. Metro Pkwy-Flowoodferc:ElectricUtilityMember 2023-12-31 C008999 Jackson South: Replace 230kV bus di 2023-01-012023-12-31 C008999 Indianola: Replace Control House &ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-In 2023-01-012023-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2023-01-012023-12-31 C008999 NEW HEBRON, Distribution, Unattended 2023-01-012023-12-31 C008999 2022 MISO Predictive Analyticsferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 PSK405-EML-Grenada Industrial Park 2023-01-012023-12-31 C008999 MS FEEDER INVESTMENT, 2023, CLINTON 2023-01-012023-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3ferc:ElectricUtilityMember 2023-12-31 C008999 GREENVILLE/NORTH, Distribution, Unattended 2023-01-012023-12-31 C008999 Privilege License, Other Taxes, , 2022-12-31 C008999 Lake Cormorant-Saint Brigid Subdivi 2023-01-012023-12-31 C008999 Tillatoba-Grenada Ind 115kV Cut-In 2023-01-012023-12-31 C008999 GREENVILLE/SOUTHEAST, Distribution, Unattended 2023-01-012023-12-31 C008999 RS-39C Residential Service 2023-01-012023-12-31 C008999 RAY BRASWELL, SOUTH JACKSON 230 - [7375], Steel Tower, 1272 ACSR 2023-01-012023-12-31 C008999 PLUM POINT, Distribution, Unattended 2023-12-31 C008999 Bowling Green - Durant 115kV CAP 2023-01-012023-12-31 C008999 C6ML300090: Copiah SS - Hazlehurstferc:ElectricUtilityMember 2023-12-31 C008999 EMPLOYMENT TAXES (Account 40811) 2023-01-012023-12-31 C008999 OTHER PRODUCTION PLANTferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 RAY BRASWELL EHV, Transmission, Unattended 2023-01-012023-12-31 C008999 DSL-16 Directional Security  Lighting 2023-01-012023-12-31 C008999 CARTHAGE-CITY OF CARTHAGE LED CONVE 2023-01-012023-12-31 C008999 SCHLATER, Distribution, Unattended 2023-12-31 C008999 BRANDON, Distribution, Unattended 2023-12-31 C008999 ferc:PayrollTaxMember 2022-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 135 months beg April 2023 2023-01-012023-12-31 C008999 See Footnoteferc:ElectricUtilityMember 2022-12-31 C008999 Broadcom Licenses - 2023ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:AfterThreeYearsMember 2023-12-31 C008999 GS-299 General Lighting and Power 2023-01-012023-12-31 C008999 Mannsdale T&D D-Scoping 2023-01-012023-12-31 C008999 C6ML300092: Canton - Pickens 230kVferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:FuelTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:PayrollTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 B(2), Edison Electric Institute (3) 2023-01-012023-12-31 C008999 ferc:OtherTaxMember 2023-01-012023-12-31 C008999 2022 Woodrow Wilson Relocation 2023-01-012023-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2022-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2023-01-012023-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2022-12-31 C008999 ferc:OtherUseTaxMember 2023-01-012023-12-31 C008999 JACKSON/SOUTH, Transmission, Unattended 2023-12-31 C008999 Section 263A 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 PRELIMINARY SURVEY & INVTG CH 2023-01-012023-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-200 2023-01-012023-12-31 C008999 Changes in money pool payable - net 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:NextTwelveMonthsMember 2023-12-31 C008999 MORTON, Distribution, Unattended 2023-12-31 C008999 HN1 - Hinds LTSA Capitalferc:ElectricUtilityMember 2023-12-31 C008999 EML: 230-13.8kV | 67MVA Incremental 2023-01-012023-12-31 C008999 State Excise Tax, Excise Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2022-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 SW-Facilities Ratings WS-NERC Repferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 DESOTO, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember 2022 Woodrow Wilson Relocation 2023-12-31 C008999 MCKNIGHT, FRANKLIN 500 - [6980], Steel Tower, [3]-954 ACSR 2023-01-012023-12-31 C008999 Distribution Resiliency Planferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MISO Rider Under-Recovery MPSC Docket No. 2014-UN-132 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMemberferc:CurrentYearMember 2023-12-31 C008999 Long-Term Incentive Plan 2022-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2023-12-31 C008999 BELZONI, Distribution, Unattended 2023-12-31 C008999 CANTON/SOUTH, Distribution, Unattended 2023-12-31 C008999 Other 2023-01-012023-12-31 C008999 SIX MILE LAKE, Transmission, Unattended 2023-01-012023-12-31 C008999 EML: 13.8kV | 2.667MVA Spare Regsferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620 2023-01-012023-12-31 C008999 ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract 2023-01-012023-12-31 C008999 ferc:FederalInsuranceTaxMember 2022-12-31 C008999 WEBB, Distribution, Unattended 2023-01-012023-12-31 C008999 OTHER GENERAL & INTANGIBLE PLANTferc:ElectricUtilityMember 2023-12-31 C008999 YANDELL RD, Distribution, Unattended 2023-12-31 C008999 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER18-1247 2023-01-012023-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2023-12-31 C008999 WYNNDALE, Distribution, Unattended 2023-12-31 C008999 ferc:FebruaryMember 0 2023-01-012023-12-31 C008999 BAXTER WILSON SES SWYD, Transmission, Unattended 2023-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2023-01-012023-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2023-12-31 C008999 See Footnoteferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, ,ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Executive Vice President and General Counsel 2023-01-012023-12-31 C008999 RAYMOND, Distribution, Unattended 2023-01-012023-12-31 C008999 SOUTH CANTON, PICKENS 230 - [5270,6185], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 Distribution Resiliency Planferc:ElectricUtilityMember 2023-12-31 C008999 EML Public EV Charging Pilotferc:ElectricUtilityMember 2023-12-31 C008999 Asset Retirement Obligation - Coal 2022-12-31 C008999 ferc:ElectricUtilityMember Spencer Potash: Replace Main Breake 2023-01-012023-12-31 C008999 HLF-7 High Load Factor 2023-01-012023-12-31 C008999 ferc:SalesAndUseTaxMember 2023-12-31 C008999 C6ML300043: Horn Lake - Greenbrook 2023-01-012023-12-31 C008999 Gerald Andrus 2023-12-31 C008999 JONESTOWN SS, Transmission, Unattended 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember E. Vicksburg-E. Vicksburg 115kV CAP 2023-12-31 C008999 2.55% Series 2023-01-012023-12-31 C008999 IT software/hardware applications and software service contracts 2023-01-012023-12-31 C008999 JACKSON/WEST, Distribution, Unattended 2023-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2022-12-31 C008999 SHELBY SS, Transmission, Unattended 2023-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022 2023-01-012023-12-31 C008999 ROXIE, Distribution, Unattended 2023-01-012023-12-31 C008999 EMI - Delta Solar 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER23-2821 2023-01-012023-12-31 C008999 Leland: Replace breaker 3G05 and adferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 C6ML300079: Norrell - Tinnin Rd 230ferc:ElectricUtilityMember 2023-12-31 C008999 Lakeover-Hinds 230kV CAPferc:ElectricUtilityMember 2023-12-31 C008999 State Excise Tax, Excise Tax, , 2023-01-012023-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2023-12-31 C008999 MPSC Docket No. 2014-UN-132 - EML Formula Rate Plan 2023-12-31 C008999 JACKSON/NORTHWEST, Distribution, Unattended 2023-12-31 C008999 ATTALA, Transmission, Unattended 2023-12-31 C008999 MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan 2023-01-012023-12-31 C008999 GERALD ANDRUS SES SWYD, Transmission, Unattended 2023-01-012023-12-31 C008999 ROLLING FORK, Distribution, Unattended 2023-12-31 C008999 Other Post Retirement Plans 2023-01-012023-12-31 C008999 EMI New Nuclear, LLCferc:UnappriatedUndistributedSubsidiaryEarningsMember 2023-12-31 C008999 RALEIGH, Distribution, Unattended 2023-12-31 C008999 2023-Madison-Replace UG along 463 i 2023-01-012023-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote): 2023-01-012023-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2023-01-012023-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284)ferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 Lakeover-Hinds 230kV CAPferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 GM-Vicksburg SE Guild 5F02-N7, N8, 2023-01-012023-12-31 C008999 Other working capital 2022-01-012022-12-31 C008999 ferc:OperatingUtilityMember 2023-01-012023-12-31 C008999 Miss. Signage Rebranding Costs 2023-01-012023-12-31 C008999 ferc:OtherAdValoremTaxMember 2023-01-012023-12-31 C008999 C6ML300085: North Greenville - Striferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 NATCHEZ, Distribution, Unattended 2023-12-31 C008999 PORT GIBSON, Distribution, Unattended 2023-12-31 C008999 ferc:OtherPropertyTaxMember 2023-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2022-12-31 C008999 EMI: Camlin Pilot (Lakeover)ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Stores Expense Undistributed (Account 163)ferc:DirectPayrollDistributionMember 2023-01-012023-12-31 C008999 Purchases/Transfers:ferc:NitrogenOxideMember 2023-01-012023-12-31 C008999 RITCHIE, MOON LAKE 230 - [6320], Wood H-Frame, 1947.5 ACSR 2023-01-012023-12-31 C008999 ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract 2023-01-012023-12-31 C008999 Video Management Solution Project 2023-01-012023-12-31 C008999 EMI - Delta Solarferc:ElectricUtilityMember 2023-12-31 C008999 ferc:MarchMember 0 2023-01-012023-12-31 C008999 Term Loan 2023-01-012023-12-31 C008999 3.5% Series 2 2023-12-31 C008999 0, 0 2023-01-012023-12-31 C008999 MISO Sch 2 Reactive 2023-01-012023-06-30 C008999 SL-37 Municipal Street Lighting 2023-01-012023-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2023-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2023-01-012023-12-31 C008999 Electric Deferred Fuel Under-Recovery 2022-12-31 C008999 EML: Camlin Pilot - Baxter Wilson 2023-01-012023-12-31 C008999 BYHALIA, Distribution, Unattended 2023-12-31 C008999 WESSON, Distribution, Unattended 2023-12-31 C008999 ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract 2023-01-012023-12-31 C008999 FRANKLIN, GRAND GULF 500 - [5640], Steel Tower, 954 ACSR 2023-01-012023-12-31 C008999 Byhalia Distribution Scopingferc:ElectricUtilityMember 2023-12-31 C008999 Midnight: rpl Oil Pump on J0346ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Penton Solar, OS, 2023-01-012023-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2023-01-012023-12-31 C008999 CRM Expansion 2023-01-012023-12-31 C008999 RFL-16 Rural Flood Lighting 2023-01-012023-12-31 C008999 REX BROWN 115 SWYD, Distribution, Unattended 2023-12-31 C008999 JACKSON/WEST, Distribution, Unattended 2023-01-012023-12-31 C008999 Forest Hill: Replace Main breakersferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 HN1 - Hinds LTSA Capital 2023-01-012023-12-31 C008999 ATTALA, Distribution, Unattended 2023-12-31 C008999 T&D - Madison Substation - Feeder-Mferc:ElectricUtilityMember 2023-12-31 C008999 ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract 2023-01-012023-12-31 C008999 Deferred Electric Storm Restoration Costs 2023-01-012023-12-31 C008999 YAZOO CITY MUNICIPAL SS, Transmission, Unattended 2023-12-31 C008999 TILLATOBA, SOUTH GRENADA 230 - [2337], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 ferc:OtherStateTaxMember 2022-12-31 C008999 Asset Retirement Obligation - Coal 2023-01-012023-12-31 C008999 BROOKHAVEN/SOUTH, Distribution, Unattended 2023-12-31 C008999 Other 2023-01-012023-12-31 C008999 EMI New Nuclear, LLCferc:UnappriatedUndistributedSubsidiaryEarningsMember 2023-01-012023-12-31 C008999 Baxter Wilson install new station sferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Entergy Mississippi, LLCferc:OctoberMember 2023-01-012023-12-31 C008999 MCADAMS EHV, Transmission, Unattended 2023-01-012023-12-31 C008999 HENDERSON ROAD, Distribution, Unattended 2023-01-012023-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-1997 2023-01-012023-12-31 C008999 SLI JOB-- ROBINSONVILLE-1001 SCHULZferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 UPIC-HORN LAKE-WILLOW OAK DR-WILLOW 2023-01-012023-12-31 C008999 Receipts & Sales, Other State Tax, , 2023-01-012023-12-31 C008999 2023-Madison-Replace UG along 463 iferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Delta Steam Replace Capacitor Bank 2023-12-31 C008999 ferc:ElectricUtilityMember 2022-12-31 C008999 WOODVILLE [MS], Distribution, Unattended 2023-12-31 C008999 CANTON, Distribution, Unattended 2023-01-012023-12-31 C008999 Vegetation Management Rider Under-Recovery MPSC Docket No. 2018-UN-205 2023-12-31 C008999 GALLATIN STREET/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 Other Accounts (Specify, provide details in footnote): 2023-01-012023-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2023-01-012023-12-31 C008999 MISO Sch 2 Reactive 2023-01-012023-12-31 C008999 Formula Rate Plan Lookback True Up MPSC Docket No. 2023-01-012023-12-31 C008999 3.5% Series 1 2023-01-012023-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 C6ML300085: North Greenville - Stri 2023-01-012023-12-31 C008999 COMO, Distribution, Unattended 2023-01-012023-12-31 C008999 2020 Planning CL20-005V New Build Nferc:ElectricUtilityMember 2023-12-31 C008999 CHURCH ROAD, Distribution, Unattended 2023-12-31 C008999 ALGS-10 / Other 2023-01-012023-12-31 C008999 Mobile device services 2023-01-012023-12-31 C008999 GERALD ANDRUS, LAKE VILLAGE BAGBY 230 - [5540], Wood H-Frame, 1534.4 ACAR 2023-01-012023-12-31 C008999 DREW [MS], Distribution, Unattended 2023-12-31 C008999 ScheduleCapitalStockAbstract 2023-01-012023-12-31 C008999 PWTHR IT Systems 2023-01-012023-12-31 C008999 Greenwood:  Replace XFMR J6825 2023-01-012023-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2023-01-012023-12-31 C008999 MOORHEAD, Distribution, Unattended 2023-01-012023-12-31 C008999 Accumulated Provisions for Property Insurance (Account 2281) 2023-01-012023-12-31 C008999 Magee: Replace breaker J5820 & J582ferc:ElectricUtilityMember 2023-12-31 C008999 Drew: Add circuit switchers, replacferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 See Footnote Detail 2023-01-012023-12-31 C008999 Coal Independence 2023-01-012023-12-31 C008999 Horn Lake:  Transformer Life Extens 2023-01-012023-12-31 C008999 CO1 - Choctaw Emergency Generator 2023-01-012023-12-31 C008999 Peter S. Norgeot, Jr. - Executive Vice President and Chief Operating Officer of Entergy Corporation 2023-01-012023-12-31 C008999 TILLATOBA, Transmission, Unattended 2023-01-012023-12-31 C008999 RULEVILLE, Distribution, Unattended 2023-01-012023-12-31 C008999 RPC Equipment Upgrade - Software 2023-01-012023-12-31 C008999 Asset Retirement Obligation - Fossil 2023-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2023-12-31 C008999 Energy Efficiency Rider Under-Recovery 2023-01-012023-12-31 C008999 ferc:Quarter4Member Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 ferc:SulfurDioxideMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Corporate Franchise Tax-AR, Franchise Tax, , 2023-01-012023-12-31 C008999 ferc:LocalTaxMember 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER15-1436 2023-01-012023-12-31 C008999 ferc:TransmissionSubstationMember 2023-12-31 C008999 ferc:NitrogenOxideMember 2022-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024ferc:ElectricUtilityMember 2023-12-31 C008999 Roderick K. West - Group President Utility Operations 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Entergy Services, LLC, Income Tax, , 2023-01-012023-12-31 C008999 Durant: Add circuit switchers, repl 2023-01-012023-12-31 C008999 SOUTH CANTON, RAGSDALE 230 LN 2 - [5271], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER16-1322 2023-01-012023-12-31 C008999 MPSC Docket No. 2018-UN-205 - EML Formula Rate Plan 2023-01-012023-12-31 C008999 ferc:Quarter2Member 0 2023-01-012023-12-31 C008999 Belzoni: Install circuit switchers,ferc:ElectricUtilityMember 2023-12-31 C008999 0, 0 2023-01-012023-12-31 C008999 Spencer Potash: Replace Main Breake 2023-01-012023-12-31 C008999 Regulatory Commission, Other Taxes, , 2023-01-012023-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2023-12-31 C008999 Asset Retirement Obligation - Fossil 2022-12-31 C008999 ferc:FederalTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Mendenhall: Replace transformer J49ferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 Other Accounts (Specify, details in footnote): 2023-01-012023-12-31 C008999 Receipts & Sales, Other State Tax, , 2023-12-31 C008999 ferc:AdValoremTaxMember 2023-01-012023-12-31 C008999 Total 500kV, , , 2023-01-012023-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2023-01-012023-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2023-01-012023-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284) 2023-01-012023-12-31 C008999 ferc:PenaltyTaxMember 2023-01-012023-12-31 C008999 ferc:PenaltyTaxMember 2022-12-31 C008999 BROOKHAVEN-HWY 51-CITY OF BROOKHAVEferc:ElectricUtilityMember 2023-12-31 C008999 Common equity distributions 2023-01-012023-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-Inferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 New Endris 230kV Swtiching Stationferc:ElectricUtilityMember 2023-12-31 C008999 RPC Equipment Upgrade - Softwareferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 FOREST HILL/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:CurrentYearMemberferc:NitrogenOxideMember 2023-01-012023-12-31 C008999 GETWELL, Transmission, Unattended 2023-01-012023-12-31 C008999 HOLLANDALE, Distribution, Unattended 2023-12-31 C008999 Batesville: Replace HV breaker J048ferc:ElectricUtilityMember 2023-12-31 C008999 CL21-002V Clinton Tinnin MT02 Long 2023-01-012023-12-31 C008999 BROOKHAVEN-HWY 51-CITY OF BROOKHAVEferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 SARDIS, Distribution, Unattended 2023-12-31 C008999 ELLIOTT, Distribution, Unattended 2023-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2022-12-31 C008999 Broadcom Licenses - 2023 2023-01-012023-12-31 C008999 Belzoni: Install circuit switchers, 2023-01-012023-12-31 C008999 ferc:FederalTaxMember 2023-01-012023-12-31 C008999 SE-29 State Institutions 2023-01-012023-12-31 C008999 Pine Tree Substation T&D D-Scoping 2023-01-012023-12-31 C008999 Pine Tree - 1Y05 I-55 Crossingferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 HAINING ROAD, Distribution, Unattended 2023-12-31 C008999 2022-Part 1-UG to Repl Ohead Hoy Rdferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember Delta Steam Replace Capacitor Bank 2023-01-012023-12-31 C008999 ferc:DirectPayrollDistributionMember Accumulated Provisions for Property Insurance (Account 2281) 2023-01-012023-12-31 C008999 Non-Expense Accrued Labor 2023-01-012023-12-31 C008999 REX BROWN 230 SWYD, Transmission, Unattended 2023-12-31 C008999 Midnight: rpl ABS J0348 & Steel Busferc:ElectricUtilityMember 2023-12-31 C008999 C6ML300113: Flowers - Tinsley 115kVferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 IPS-26 Irrigation Pumping Power 2023-01-012023-12-31 C008999 CRENSHAW, Distribution, Unattended 2023-01-012023-12-31 C008999 Entergy Services, LLC, Income Tax, , 2023-01-012023-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2022-12-31 C008999 Crenshaw:  Add Circuit Switcherferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:ElectricUtilityMember C6ML300045: Canton - S. Canton 230k 2023-12-31 C008999 IPS-26 Irrigation Pumping Power 2023-01-012023-12-31 C008999 , , 2023-01-012023-12-31 C008999 HORN LAKE, GETWELL 230 - [6186], Concrete Pole, 1272 ACSR 2023-01-012023-12-31 C008999 RAY BRASWEL, REX BROWN 230 - [7100], Wood H-Frame, 1272 ACSS 2023-01-012023-12-31 C008999 GREENVILLE, Distribution, Unattended 2023-01-012023-12-31 C008999 TYLERTOWN, Distribution, Unattended 2023-01-012023-12-31 C008999 VICKSBURG/EAST, Distribution, Unattended 2023-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2023-12-31 C008999 HORN LAKE, Transmission, Unattended 2023-12-31 C008999 ferc:LocalTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 MCADAMS, INDIANOLA 230 - [6410], Wood H-Frame, 1272 ACSR 2023-01-012023-12-31 C008999 ferc:SeveranceTaxMember 2023-01-012023-12-31 C008999 MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb)ferc:ElectricUtilityMember 2023-12-31 C008999 DREW [MS], Distribution, Unattended 2023-01-012023-12-31 C008999 EDWARDS, Distribution, Unattended 2023-12-31 C008999 OTHER GENERAL & INTANGIBLE PLANT 2023-01-012023-12-31 C008999 EMI: Camlin Pilot (Freeport)ferc:ElectricUtilityMember 2023-12-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2022-12-31 C008999 ferc:ElectricUtilityMember Dundee 115kV SS Solar J1440 Scoping 2023-12-31 C008999 Allowances Usedferc:NitrogenOxideMember 2023-01-012023-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2023-01-012023-12-31 C008999 RAYMOND, Distribution, Unattended 2023-12-31 C008999 Yazoo City SW St:  Rpl XFMR 2023-01-012023-12-31 C008999 LAKEOVER, HINDS2 BLACKSTART GT3 - [2342], Steel Pole, 954 ACSR 2023-01-012023-12-31 C008999 Qualified Pension funded status 2023-01-012023-12-31 C008999 CO1 LTSA Capitalization- CT-301ferc:ElectricUtilityMember 2023-12-31 C008999 HAZLEHURST, Distribution, Unattended 2023-01-012023-12-31 C008999 C6ML300045: Canton - S. Canton 230k 2023-01-012023-12-31 C008999 MONUMENT STREET/JACKSON, Distribution, Unattended 2023-01-012023-12-31 C008999 ferc:OtherAllocatedTaxMember 2023-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2023-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-2693 2023-01-012023-12-31 C008999 ferc:SalesAndUseTaxMemberferc:ElectricUtilityMember 2023-01-012023-12-31 C008999 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2023-12-31 C008999 CATLETT, YANDELL RD 230 - [2343], Steel Pole, 1272 ACSR 2023-01-012023-12-31 C008999 Formula Rate Plan Lookback True Up MPSC Docket No. 2023-12-31 C008999 Pine Tree Substation T&D D-Scopingferc:ElectricUtilityMember 2023-12-31 C008999 Midnight: rpl ABS J0348 & Steel Bus 2023-01-012023-12-31 C008999 ferc:DecemberMember Entergy Mississippi, LLC 2023-01-012023-12-31 C008999 EML: Camlin Mon S Grenada AT1ferc:ElectricUtilityMember 2023-12-31 C008999 3.85% Series 1 2023-12-31 iso4217:USD utr:T utr:MW utr:MWh iso4217:USD iso4217:USD utr:MMBTU utr:Btu utr:kWh xbrli:pure utr:mi iso4217:USD utr:Mcf xbrli:pure utr:Btu iso4217:USD utr:kW utr:kWh utr:Mcf iso4217:USD utr:kWh utr:T utr:kV iso4217:USD utr:bbl utr:bbl utr:MVA utr:mi
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

Entergy Mississippi, LLC
Year/Period of Report

End of:
2023
/
Q4


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent

Entergy Mississippi, LLC
02 Year/ Period of Report


End of:
2023
/
Q4
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

308 East Pearl Street, Jackson, Mississippi 39201
05 Name of Contact Person

Gina G. Bellott
06 Title of Contact Person

Sr. Staff Accountant
07 Address of Contact Person (Street, City, State, Zip Code)

639 Loyola Avenue, New Orleans, Louisiana 70113
08 Telephone of Contact Person, Including Area Code

(504) 858-3276
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

04/15/2024
Annual Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Reginald T. Jackson
02 Title

Sr VP & Chief Accounting Officer
03 Signature

Reginald T. Jackson
04 Date Signed (Mo, Da, Yr)

04/15/2024
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
LIST OF SCHEDULES (Electric Utility)

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
NA
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
NA
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
NA
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
NA
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
NA
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
NA
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
NA
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
NA
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
NA
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
NA
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
NA
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
NA
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
NA
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
NA
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
NA
66.1
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
NA
66.2
ScheduleEnergyStorageOperationsSmallPlantsAbstract
Energy Storage Operations (Small Plants)
419
NA
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
NA
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
NA
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Reginald T. Jackson

Senior Vice President and Chief Accounting Officer

639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
TX

Date of Incorporation:
2018-09-17

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

N/A

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Mississippi - Electric Utility Service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
As of December 31, 2023, all of the common membership interests in Entergy Mississippi are held by Entergy Utility Holding Company. As of December 31, 2023, Entergy Utility Holding Company's membership interests are held by:

    Entergy Corporation 3.7% 459,503 shares
Entergy Utility Affiliates 23.3% multiple securities
Entergy Utility Assets 31.2% 3,891,055 shares
Entergy Utility Enterprises 13.2% 1,640,560 shares
Entergy Utility Group 2.8% 350,173 shares
  EUHC Holdings 24.1% 3,006,086 shares
Unaffiliated third parties 1.5% multiple securities


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
EMI New Nuclear, LLC
100
2
Entergy Power & Light Company
100
3
The Light, Heat and Water Company of Jackson, Mississippi
100
4
Jackson Gas Light Company
100
5
Mississippi Power & Light Company
100
6
MS Sunflower Partnership, LLC
100


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
President and Chief Executive Officer of Entergy Mississippi
Haley R. Fisackerly
431,421
2
Chairman of the Board of Entergy Corporation (1)
Leo P. Denault
2023-02-01
3
Chairman of the Board of Entergy Corporation (2)
Andrew S. Marsh
2023-02-01
4
Chief Executive Officer of Entergy Corporation
Andrew S. Marsh
5
Executive Vice President and Chief Financial Officer
Kimberly A. Fontan
6
Executive Vice President and Chief Operating Officer of Entergy Corporation
Peter S. Norgeot, Jr.
7
Executive Vice President and General Counsel
Marcus V. Brown
8
Group President Utility Operations
Roderick K. West
9
Senior Vice President and Chief Accounting Officer
Reginald T. Jackson
10
Vice President and General Tax Counsel
Steven W. Brady


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(b) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(c) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(d) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(e) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(f) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(g) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(h) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(i) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi
308 East Pearl Street, Jackson, MS 39201
false
false
2
Kimberly A. Fontan - Executive Vice President and Chief Financial Officer
639 Loyola Avenue, New Orleans, LA 70113
true
false
3
Roderick K. West - Group President Utility Operations
639 Loyola Avenue, New Orleans, LA 70113
true
false
4
Peter S. Norgeot, Jr. - Executive Vice President and Chief Operating Officer of Entergy Corporation
639 Loyola Avenue, New Orleans, LA 70113
true
false


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff
Docket No. ER13-1508
2
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER16-2199
3
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER18-1247
4
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER19-747
5
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-915
6
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1720
7
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1997
8
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-2169
9
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER22-489
10
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER22-2332
11
Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1
Docket No. ER13-948
12
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER14-649
13
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-358
14
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-1436
15
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-227
16
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-1322
17
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-215
18
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1549
19
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1777
20
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-2579
21
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1260
22
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1982
23
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-652
24
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-1503
25
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-827
26
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1449
27
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1472
28
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-200
29
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-262
30
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-2693
31
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-1602
32
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-2202
33
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-2562
34
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER23-2707
35
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER23-1228
36
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER23-2821


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
03/15/2023
ER23-1387
(a)
EML Annual Informational MISO Attachment O Transmission Formula Rate Update


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfFiling
Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2022 update was filed on March 15, 2023 in Docket No. ER23-1387. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2022 through May 31, 2023 through the application of data for Calendar Year 2021 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
NONE


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1.None
2. None
3. None
4. None
5. None
6. See Entergy Mississippi's 2023 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, and utility support employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective October 15, 2022 through October 15, 2025. Effective October 16, 2023, the wage increase was 2.5%.

Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 16, 2022 through April 16, 2026. Effective April 16, 2023, the wage increase was 2.5%.

Effective April 1, 2023, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 4.0%.
9. See Entergy Mississippi’s 2023 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
13. See Entergy Mississippi’s 2023 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2023.
14. Not applicable


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
7,306,663,808
6,948,265,708
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
157,119,085
169,802,754
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
7,463,782,893
7,118,068,462
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
(a)
2,155,897,819
(b)
2,105,185,734
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
5,307,885,074
5,012,882,728
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
5,307,885,074
5,012,882,728
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
5,025,426
5,025,426
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
528,511
513,554
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
101,256,108
95,822,307
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
656,004
34,459,021
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
106,409,027
134,793,200
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
28,466
25,507
36
SpecialDeposits
Special Deposits (132-134)
37
WorkingFunds
Working Fund (135)
43
139
38
TemporaryCashInvestments
Temporary Cash Investments (136)
809,835
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
121,388,981
99,503,754
41
OtherAccountsReceivable
Other Accounts Receivable (143)
17,695,868
34,563,849
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
3,311,737
2,471,515
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
4,997,470
37,673,103
45
FuelStock
Fuel Stock (151)
227
16,188,254
15,537,354
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
89,885,458
80,173,375
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
7,406
10,807
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
5,640,795
4,172,529
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
19,200,941
16,275,451
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
10,651
117,114
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
71,465,082
73,473,246
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
8,841
29,585
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
1,358,301
568,661
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
344,547,052
360,462,794
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
21,332,182
20,097,508
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
392,003,456
514,679,808
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
9,958,284
9,308,250
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
139,828
80,244
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
2,690,236
2,671,935
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
9,975,768
10,866,706
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
53,598,274
570,309,487
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
489,418,372
1,127,853,450
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
6,248,259,525
6,635,992,172


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $186,178,032.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $159,380,684.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
329,266,361
329,266,361
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
1,865,532,611
1,707,662,335
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
4,403,986
209,536
13
ReacquiredCapitalStock
(Less) Reacquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
2,190,394,986
2,037,138,232
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
2,245,000,000
2,195,000,000
19
ReacquiredBonds
(Less) Reacquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
150,000,000
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
11,804,774
12,262,053
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
6,258,223
6,458,523
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
2,250,546,551
2,350,803,530
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
26,501,028
23,701,837
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
30,995,974
33,644,644
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
4,356,054
3,800,680
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
41,987,676
32,584,563
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
4,000
64,000
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
8,229,011
7,797,108
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
28,098,391
36,423,706
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
38
AccountsPayable
Accounts Payable (232)
92,322,729
142,339,646
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
133,829,288
60,798,343
41
CustomerDeposits
Customer Deposits (235)
92,637,435
89,667,860
42
TaxesAccrued
Taxes Accrued (236)
262
113,909,268
279,673,086
43
InterestAccrued
Interest Accrued (237)
23,636,861
21,308,245
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
2,863,999
2,745,088
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
5,435,293
1,098,451
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
9,114,288
8,515,017
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
10,145,279
24,003,048
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
483,894,440
630,148,784
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
32,659,183
28,563,547
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
13,810,508
14,591,466
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
19,554,236
59,763,946
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
360,097,781
286,087,433
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reacquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
800,329,215
716,929,779
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
68,874,234
475,541,749
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,295,325,157
1,581,477,920
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
6,248,259,525
6,635,992,172


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
1,796,819,262
1,622,375,772
1,796,819,262
1,622,375,772
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
1,083,824,007
800,037,208
1,083,824,007
800,037,208
5
MaintenanceExpense
Maintenance Expenses (402)
320
85,609,970
94,799,001
85,609,970
94,799,001
6
DepreciationExpense
Depreciation Expense (403)
336
230,361,502
219,099,143
230,361,502
219,099,143
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
35,671
11,486
35,671
11,486
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
25,665,402
23,210,109
25,665,402
23,210,109
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
2,641,604
2,681,141
2,641,604
2,681,141
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
38,042,155
136,047,708
38,042,155
136,047,708
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
158,534,821
119,434,556
158,534,821
119,434,556
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
145,632,431
137,539,778
145,632,431
137,539,778
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
99,452,892
90,573,212
99,452,892
90,573,212
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
24,269,432
12,890,589
24,269,432
12,890,589
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
818,172,888
802,986,873
818,172,888
802,986,873
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
636,657,862
855,301,008
636,657,862
855,301,008
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
795,902
3,664,589
795,902
3,664,589
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
33
33
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
431,903
569,340
431,903
569,340
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
1,510,706,591
1,349,374,613
1,510,706,591
1,349,374,613
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
286,112,671
273,001,159
286,112,671
273,001,159
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
14,957
15,069
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
4,613,522
213,506
37
InterestAndDividendIncome
Interest and Dividend Income (419)
1,790,811
486,056
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
8,551,586
6,125,356
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
1,787,927
10,950,871
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
141,009
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
7,501,845
17,901,729
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
268,683
12,442
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
1,066,235
4,331,458
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
52,152
116,214
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
2,195,587
2,312,522
49
OtherDeductions
Other Deductions (426.5)
3,029,969
2,351,377
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
6,612,626
9,124,013
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
245
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
1,305,496
520,049
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
327,192
130,338
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
1,632,688
650,142
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
2,521,907
9,427,858
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
91,374,316
81,746,939
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
2,106,704
1,907,544
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
917,109
1,293,069
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
457,279
457,279
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
1,492,102
398,719
68
OtherInterestExpense
Other Interest Expense (431)
3,424,195
2,770,677
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
3,479,323
2,800,404
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
95,377,824
84,859,265
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
193,256,754
197,569,752
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
0
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
193,256,754
197,569,752


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report


End of:
2023
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
1,707,662,335
1,510,306,089
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
197,870,276
197,356,246
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
30.1
DividendsDeclaredCommonStock
Common equity distributions
40,000,000
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
40,000,000
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
1,865,532,611
1,707,662,335
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
1,865,532,611
1,707,662,335
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
209,536
3,970
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
4,613,522
213,506
51
DividendsReceived
(Less) Dividends Received (Debit)
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)
4,403,986
209,536


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
193,256,754
197,569,752
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
259,136,082
245,571,219
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt
3,023,813
3,200,613
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
181,515,026
52,314,135
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
795,902
3,664,589
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
3,627,421
65,844,707
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
11,831,249
19,953,667
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
3,401
9,363
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
214,189,987
169,656,068
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
122,676,352
57,405,109
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
74,010,348
788,246
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
8,551,586
6,125,356
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other working capital
10,002,682
5,051,952
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other
35,646,582
18,148,573
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
556,231,209
404,143,763
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
553,244,089
533,495,870
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
8,551,586
6,125,356
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
544,692,503
527,370,514
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
5,557,754
95,606,559
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Changes in money pool receivable - net
26,879,352
13,576,864
53.2
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other
(a)
742,064
1,273,314
53.3
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Receipt from storm reserve escrow account
34,545,081
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
489,567,888
610,673,523
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
296,832,753
149,266,350
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Change in credit borrowings - net
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
296,832,753
149,266,350
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
400,000,000
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other
(b)
1,928,055
10,474,657
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Changes in money pool payable - net
73,768,813
76.3
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Common equity distributions paid
40,000,000
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
67,470,379
159,741,007
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
807,058
46,788,753
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
835,481
47,624,234
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
28,423
835,481


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other investing activities include:
2023 2022
Interest on prefunded property insurance escrow ($1,651,983) ($363,159)
Other special funds (236) — 
Captive insurance deposit 910,155  (910,155)
Total ($742,064) ($1,273,314)
(b) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other financing activities include:
2023 2022
Customer Advances for Construction $4,095,636  $12,103,477 
Financing Leases (2,167,581) (1,628,820)
Total $1,928,055  $10,474,657 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:

Cash and Cash Equivalents at December 31, 2023
Cash (Account 131)$28,466 
Working Fund (Account 135)(43)
Total$28,423 
Supplemental Disclosure of Cash Flow Statement
Cash paid during the period for:(in 000s)
Interest - net of amount capitalized$94,962 
Income Taxes$50,869 

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2021 data for the statement of income, retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.

GAAP requires that Entergy Mississippi consolidate MS Sunflower Partnership, LLC due to the significant influence it exerts as the managing member of the partnership, whereas Entergy Mississippi's investment in the partnership is presented in the FERC Form 1 as an equity-method investment. Additionally, GAAP requires Entergy Mississippi to record the earnings it receives from the partnership using the hypothetical-liquidation at book value (HLBV) method of accounting because the limited liability agreement forming the partnership stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Mississippi and the other investor in the partnership. In contrast, Entergy Mississippi recognizes its share in the partnership earnings based on its ownership-percentage in the partnership for reporting in the FERC Form 1.

C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2023. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.
"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
2023
2.7%
2.6%
3.6%
3.3%
4.0%
1.6%
2022
2.7%
2.4%
3.6%
3.2%
3.1%
2.0%
2021
2.7%
2.4%
3.6%
3.2%
3.2%
1.9%


Jointly-Owned Generating Stations
Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:

Generating Stations
Fuel Type
Total Megawatt Capability (a)
Ownership
Investment
Accumulated Depreciation
(In Millions)
Utility:
Entergy Arkansas -
Independence
Unit 1
Coal
824
31.50%
$145
$108
Independence
Common Facilities
Coal
15.75%
$42
$31
White Bluff
Units 1 and 2
Coal
1,244
57.00%
$593
$404
Ouachita (b)
Common Facilities
Gas
66.67%
$173
$159
Union (c)
Common Facilities
Gas
25.00%
$29
$12
Entergy Louisiana -
Roy S. Nelson
Unit 6
Coal
514
40.25%
$299
$224
Roy S. Nelson
Unit 6 Common Facilities
Coal
22.04%
$22
$11
Big Cajun 2
Unit 3
Coal
548
24.15%
$149
$136
Big Cajun 2
Unit 3 Common Facilities
Coal
8.05%
$5
$3
Ouachita (b)
Common Facilities
Gas
33.33%
$91
$79
Acadia
Common Facilities
Gas
50.00%
$22
$3
Union (c)
Common Facilities
Gas
50.00%
$59
$14
Entergy Mississippi -
Independence
Units 1 and 2 and Common Facilities
Coal
1,666
25.00%
$293
$182
Entergy New Orleans -
Union (c)
Common Facilities
Gas
25.00%
$30
$10
Entergy Texas -
Roy S. Nelson
Unit 6
Coal
514
29.75%
$211
$141
Roy S. Nelson
Unit 6 Common Facilities
Coal
16.30%
$8
$4
Big Cajun 2
Unit 3
Coal
548
17.85%
$112
$101
Big Cajun 2
Unit 3 Common Facilities
Coal
5.95%
$4
$2
Montgomery County
Unit 1
Gas
915
92.44%
$745
$54
System Energy -
Grand Gulf (d)
Unit 1
Nuclear
1,383
90.00%
$5,499
$3,494
Other:
Independence
Unit 2
Coal
842
14.37%
$79
$59
Independence
Common Facilities
Coal
7.18%
$21
$15
Roy S. Nelson
Unit 6
Coal
514
10.90%
$120
$74
Roy S. Nelson
Unit 6 Common Facilities
Coal
5.97%
$3
$1
a.“Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.
c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.
d.Includes a leasehold interest held by System Energy.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers.

Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the
Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement.

In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made.

Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase,
normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis.

Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.

Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions
Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.


NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Regulatory activity regarding the Tax Cuts and Jobs Act

See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.

2023
2022
(In Millions)
Entergy Arkansas (a)
($88.3)
$208.6
Entergy Louisiana (b)
$192.9
$327.3
Entergy Mississippi
($130.6)
$143.2
Entergy New Orleans (b)
$10.2
$14.2
Entergy Texas
$139.0
$258.1

a.Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months.
b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Mississippi
Entergy Mississippi’s rate schedules include an energy cost recovery rider and a power management rider, both of which are adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi recovers fuel and purchased energy costs through its energy cost recovery rider and recovers costs associated with natural gas hedging and capacity payments through its power management rider. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In November 2020, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an over-recovery of approximately $24.4 million as of September 30, 2020. In January 2021 the MPSC approved the proposed energy cost factor effective for February 2021 bills.

In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills.

SeeComplaints Against System Energy - System Energy Settlement with the MPSC” below for discussion of the settlement agreement filed with the FERC in June 2022. The settlement, which was approved by the FERC in November 2022, provided for a refund of $235 million from System Energy to Entergy Mississippi. In July 2022 the MPSC directed the disbursement of settlement proceeds, ordering Entergy Mississippi to provide a one-time $80 bill credit to each of its approximately 460,000 retail customers to be effective during the September 2022 billing cycle and to apply the remaining proceeds to Entergy Mississippi’s under-recovered deferred fuel balance. In accordance with the MPSC’s directive, Entergy Mississippi provided approximately $36.7 million in customer bill credits as a result of the settlement. In November 2022, Entergy Mississippi applied the remaining settlement proceeds in the amount of approximately $198.3 million to Entergy Mississippi’s under-recovered deferred fuel balance.

Entergy Mississippi had a deferred fuel balance of approximately $291.7 million under the energy cost recovery rider as of July 31, 2022, along with an over-recovery balance of $51.1 million under the power management rider. Without further action, Entergy Mississippi anticipated a year-end deferred fuel balance of approximately $200 million after application of a portion of the System Energy settlement proceeds, as discussed above. In September 2022, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider. Entergy Mississippi proposed five monthly incremental adjustments to the net energy cost factor designed to collect the under-recovered fuel balance as of July 31, 2022 and to reflect the recovery of a higher natural gas price. Entergy Mississippi also proposed five monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance as of July 31, 2022. In October 2022 the MPSC approved modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider. The MPSC approved dividing the energy cost recovery rider interim adjustment into two components that would allow Entergy Mississippi to (1) recover a natural gas fuel rate that is better aligned with current prices; and (2) recover the estimated under-recovered deferred fuel balance as of September 30, 2022 over a period of 20 months. The
MPSC approved six monthly incremental adjustments to the net energy cost factor designed to reflect the recovery of a higher natural gas price. The MPSC also approved six monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance. In accordance with the order of the MPSC, Entergy Mississippi did not file an annual redetermination of the energy cost recovery rider or the power management rider in November 2022.

In June 2023 the MPSC approved the joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2023 formula rate plan filing. The stipulation directed Entergy Mississippi to make a compliance filing to revise its power management cost adjustment factor, to revise its grid modernization cost adjustment factor, and to include a revision to reduce the net energy cost factor to a level necessary to reflect an average natural gas price of $4.50 per MMBtu. The MPSC approved the compliance filing in June 2023, effective for July 2023 bills. See “Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2023 Formula Rate Plan Filing” below for further discussion of the 2023 formula rate plan filing and the joint stipulation agreement.

In November 2023 Entergy Mississippi filed its annual redeterminations of the energy cost factor and the power management cost adjustment factor. The calculation of the annual factor for the energy cost recovery rider included a projected over-recovery balance of approximately $142 million at the end of January 2024. The calculation of the annual factor for the power management rider included a projected under-recovery of $47 million at the end of January 2024. In January 2024 the MPSC approved the proposed energy cost factor and the proposed power management cost factor effective for February 2024 bills.

Retail Rate Proceedings

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing showed a $95.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, was capped at 4% of retail revenues, which equated to a revenue change of $44.3 million. The 2021 evaluation report also included $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs were not subject to the 4% cap and resulted in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compared actual 2020 results to the approved benchmark return on rate base and reflected the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing included an interim capacity adjustment true-up for the Choctaw Generating Station, which increased the look-back interim rate adjustment by $1.7 million. These interim rate adjustments totaled $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which were not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.
In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which was below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through June 2022. This included $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. The joint stipulation also included Entergy Mississippi’s quantification and methodology for calculating incremental COVID-19 bad debt expenses and provided for Entergy Mississippi to continue to defer these incremental COVID-19 bad debt expenses through December 2021. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing showed a $69 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, was capped at 4% of retail revenues, which equated to a revenue change of $48.6 million. The 2021 look-back filing compared actual 2021 results to the approved benchmark return on rate base and reflected the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022. With the implementation of the interim formula rate plan rates, Entergy Mississippi began recovery of the bad debt expense deferral resulting from the COVID-19 pandemic over a three-year period.

In June 2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2022 test year filing that resulted in a total rate increase of $48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2021 look-back filing reflected an earned return on rate base of 5.99% in calendar year 2021, which was below the look-back bandwidth, resulting in a $34.3 million increase in the formula rate plan revenues on an interim basis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective in August 2022. In July 2022, Entergy Mississippi recorded regulatory credits of $22.6 million to reflect the effects of the joint stipulation. In August 2022 an intervenor filed a statutorily-authorized direct appeal to the Mississippi Supreme Court seeking review of the MPSC’s July 2022 order approving the joint stipulation confirming Entergy Mississippi’s 2022 formula rate plan filing. Formula rate plan rates are not stayed or otherwise impacted while the appeal is pending.

In July 2022 the MPSC directed Entergy Mississippi to flow $14.1 million of the power management rider over-recovery balance to customers beginning in August 2022 through December 2022 to mitigate the bill impact of the increase in formula rate plan revenues.

2023 Formula Rate Plan Filing
In March 2023, Entergy Mississippi submitted its formula rate plan 2023 test year filing and 2022 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2022 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2023 calendar year to be below the formula rate plan bandwidth. The 2023 test year filing showed a $39.8 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 6.67%, within the formula rate plan bandwidth. The 2022 look-back filing compared actual 2022 results to the approved benchmark return on rate base and reflected the need for a $19.8 million temporary increase in formula rate plan revenues, including the refund of a $1.3 million over-recovery resulting from the demand-side management costs true-up for 2022. In fourth quarter 2022, Entergy Mississippi recorded a regulatory asset of $18.2 million in connection with the look-back feature of the formula rate plan to reflect that the 2022 estimated earned return was below the formula rate plan bandwidth. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $27.9 million interim rate increase, reflecting a cap equal to 2% of 2022 retail revenues, effective in April 2023.

In May 2023, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed a 2023 test year filing resulting in a total revenue increase of $26.5 million for 2023. Pursuant to the joint stipulation, Entergy Mississippi’s 2022 look-back filing reflected an earned return on rate base of 6.10% in calendar year 2022, which was below the look-back bandwidth, resulting in a $19.0 million increase in the formula rate plan revenues on an interim basis through June 2024. Entergy Mississippi recorded a regulatory credit of $0.8 million in June 2023 to reflect the increase in the look-back regulatory asset. In addition, certain long-term service agreement and conductor handling costs were authorized for realignment from the formula rate plan to the annual power management and grid modernization riders effective January 2023, resulting in regulatory credits recorded in June 2023 of $4.1 million and $4.3 million, respectively. Also, the amortization of Entergy Mississippi’s COVID-19 bad debt expense deferral was suspended for calendar year 2023 and will resume in 2024. In June 2023 the MPSC approved the joint stipulation with rates effective in July 2023.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding.

After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision.

The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System
Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.

In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology.

In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal.

The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties.
Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million.

In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit.

In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:

Total refunds including interest
Payment/(Receipt)
(In Millions)
Principal
Interest
Total
Entergy Arkansas
$68
$67
$135
Entergy Louisiana
($30)
($29)
($59)
Entergy Mississippi
($18)
($18)
($36)
Entergy New Orleans
($3)
($4)
($7)
Entergy Texas
($17)
($16)
($33)

As described above, the FERC’s opportunity sales orders were appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

System Energy Settlement with the MPSC

In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorializes the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s
owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered. The settlement therefore limits System Energy’s overall refund exposure associated with the identified proceedings because they will be resolved completely as between the Entergy parties and the MPSC.

The settlement provided for a black-box refund of $235 million from System Energy to Entergy Mississippi, which was to be paid within 120 days of the settlement’s effective date (either the date of the FERC approval of the settlement without material modification, or the date that all settling parties agree to accept modifications or otherwise modify the settlement in response to a proposed material modification by the FERC). In addition, beginning with the July 2022 service month, the settlement provided for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates. The settlement was approved by the MPSC in June 2022 and the FERC in November 2022.

System Energy previously recorded a provision and associated liability of $37 million for elements of the applicable litigation. In June 2022, System Energy recorded a regulatory charge of $551 million ($413 million net-of-tax), increasing the regulatory liability to $588 million, which consisted of $235 million for the settlement with the MPSC and $353 million for potential future refunds to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. System Energy paid the black-box refund of $235 million to Entergy Mississippi in November 2022. See “System Energy Regulatory Liability for Pending Complaints” below for discussion of the regulatory liability related to complaints against System Energy as of December 31, 2023.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. Entergy Mississippi’s storm damage provision balance has been less than $10 million since May 2019, and Entergy Mississippi has been billing the monthly storm damage provision since July 2019.

In December 2023 Entergy Mississippi filed a Notice of Storm Escrow Disbursement and Request for Interim Relief notifying the MPSC that Entergy Mississippi had requested disbursement of approximately $34.5 million of storm escrow funds from its restricted storm escrow account. The filing also requested authorization from the MPSC, on a temporary basis, that the $34.5 million of storm escrow funds be credited to Entergy Mississippi’s storm damage provision, pending the MPSC’s review of Entergy Mississippi’s storm-related costs, and that Entergy Mississippi continue to bill its monthly storm damage provision without suspension in the event the storm damage provision balance exceeds $15 million, in anticipation of a subsequent filing by Entergy Mississippi in this proceeding. The storm damage reserve exceeded $15 million upon receipt of the storm escrow funds. Because the MPSC had not entered an order on Entergy Mississippi’s filing on the requested relief to continue billing this provision, Entergy Mississippi suspended billing the monthly storm damage provision effective with February 2024 bills.

NOTE 3. INCOME TAXES
Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Federal net operating losses before 1/1/2018
$— million
$0.8 billion
$— million
$0.1 billion
$— million
$— million
Year(s) of expiration
N/A
2035-2037
N/A
2037
N/A
N/A
Federal net operating losses - 1/1/2018 forward
$0.5 billion
$2.8 billion
$10.8 million
$17.7 million
$1.8 billion
$0.1 billion
Year(s) of expiration
N/A
N/A
N/A
N/A
N/A
N/A
State net operating losses
$0.4 billion
$5.7 billion
$0.1 billion
$0.2 billion
$1 million
$0.2 billion
Year(s) of expiration
2028-2032
N/A
2040-2042
N/A
2028
N/A
Misc. federal credits
$10 million
$16.9 million
$3.9 million
$16.1 million
$0.8 million
$4.8 million
Year(s) of expiration
2038-2043
2035-2043
2038-2043
2037-2043
2039-2043
2029-2043
State credits
$— million
$— million
$8 million
$— million
$1.6 million
$19 million
Year(s) of expiration
N/A
N/A
2024-2026
N/A
2027-2033
2024-2027

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2023
$1,452,819
$1,350,836
$547,548
$638,726
$389,366
$23,702
Additions based on tax positions related to the current year (a)
2,249
332,320
209
78
196
752
Additions for tax positions of prior years
94,793
Reductions for tax positions of prior years (b)
(148,558)
(458,072)
(16,853)
(191,336)
(67,156)
(9,532)
Settlements (b)
(1,237,313)
(361,041)
(525,251)
(428,137)
(1,994)
(621)
Gross balance at December 31, 2023
69,197
864,043
5,653
19,331
415,205
14,301
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(34,683)
(735,612)
(3,778)
(11,721)
(381,561)
(14,301)
Unrecognized tax benefits net of unused tax attributes
$34,514
$128,431
$1,875
$7,610
$33,644
$—

2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2022
$1,408,494
$604,628
$549,569
$639,497
$552,295
$23,356
Additions based on tax positions related to the current year (a)
40,502
750,320
185
72
173
690
Additions for tax positions of prior years
6,233
10,262
1,122
393
801
761
Reductions for tax positions of prior years
(2,410)
(14,374)
(3,328)
(1,236)
(163,903)
(1,105)
Gross balance at December 31, 2022
1,452,819
1,350,836
547,548
638,726
389,366
23,702
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(1,277,414)
(1,328,916)
(504,940)
(455,928)
(377,054)
(23,702)
Unrecognized tax benefits net of unused tax attributes
$175,405
$21,920
$42,608
$182,798
$12,312
$—

2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2021
$1,364,635
$640,295
$549,717
$639,546
$521,932
$21,652
Additions based on tax positions related to the current year
30,419
13,437
684
1,050
32,616
1,753
Additions for tax positions of prior years
15,013
9,304
1,504
6
2,315
1,897
Reductions for tax positions of prior years
(1,573)
(58,408)
(2,336)
(1,105)
(4,568)
(1,946)
Gross balance at December 31, 2021
1,408,494
604,628
549,569
639,497
552,295
23,356
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(992,643)
(604,628)
(388,728)
(484,899)
(540,694)
(8,576)
Unrecognized tax benefits net of unused tax attributes
$415,851
$—
$160,841
$154,598
$11,601
$14,780

a.The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations.
b.Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in Income Tax Audits - 2016-2018 IRS Audit” below.

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:

December 31,
2023
2022
2021
(In Millions)
Entergy Arkansas
$57.2
$377.9
$262.1
Entergy Louisiana
$862.5
$720.8
$66.3
Entergy Mississippi
$1.0
$151.2
$51.7
Entergy New Orleans
$18.2
$310.7
$228.6
Entergy Texas
$2.9
$3.3
$2.6
System Energy
$3.1
$2.5
$1.7

Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows:

December 31,
2023
2022
2021
(In Millions)
Entergy Arkansas
$7.8
$4.3
$2.7
Entergy Louisiana
$1.5
$4.1
$3.7
Entergy Mississippi
$2.1
$3.1
$2.4
Entergy New Orleans
$0.6
$6.4
$5.2
Entergy Texas
$—
$1.1
$1.1
System Energy
$1.9
$1.9
$12.1

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows:

2023
2022
2021
(In Millions)
Entergy Arkansas
$3.5
$1.6
$0.4
Entergy Louisiana
($2.6)
$0.4
$0.3
Entergy Mississippi
($1.0)
$0.7
$0.5
Entergy New Orleans
($5.8)
$1.2
$1.3
Entergy Texas
($1.1)
$—
$0.2
System Energy
$—
($10.2)
$0.2

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2016-2018 IRS Audit

The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023.
Mark-to-Market Method of Accounting

In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “Regulatory and Other Matters” section below.

Reduction of Net Operating Loss Carryovers

The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024.

Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023.

Regulatory and Other Matters

Reversal of net deferred credits associated with the accounting for income taxes upon the resolution of the IRS audit resulted in a reduction/(increase) of income tax expense of $9 million, $42 million, ($2) million, $2 million, $2 million, and $1 million for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, respectively.

Included in the effect of the IRS audit on the results of operations was the measurement of deferred tax assets and liabilities influenced by the 2017 enactment of the Tax Cuts and Jobs Act income tax rate change discussed below. With the conclusion of the audit, there are no remaining federal unrecognized tax benefits affected by the rate differential which could impact income tax expense and the regulatory liability for income taxes in future periods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. Entergy had remaining regulatory liabilities of $1.0 billion and $1.3 billion as of December 31, 2023 and December 31, 2022, respectively, mainly associated with the re-measurement of deferred tax assets and liabilities from the income tax rate change, subsequent amortization of excess ADIT, and payments to customers since the enactment of the TCJA. In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes
includes other regulatory assets and liabilities for income taxes mainly for AFUDC, which is described in Note 1 to the financial statements.

Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of (1) the reduction of the net deferred tax liability resulting in excess ADIT, and (2) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows:

2023
2022
(In Millions)
Entergy Arkansas
$392
$435
Entergy Louisiana
$194
$338
Entergy Mississippi
$189
$202
Entergy New Orleans
$36
$40
Entergy Texas
$115
$133
System Energy
$107
$111

Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements.

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas.

Inflation Reduction Act of 2022

The Inflation Reduction Act of 2022, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power plants. Additionally, the Inflation Reduction Act of 2022 enacted a 1% excise tax
on the buyback of public company stock and a new corporate alternative minimum tax. There are no effects on the financial statements of Entergy or the Registrant Subsidiaries as of and for the years ended December 31, 2023 and 2022 related to the enactment of the law.

Tax Accounting Methods

Certain Entergy subsidiaries have elected to apply the mark-to-market method of accounting for income tax return purposes to wholesale power purchase agreements as appropriate under the Internal Revenue Code and U.S. Treasury Regulations. The mark-to-market tax gain or loss computed each year is based on an estimated fair market valuation which includes analyses of market prices and conditions.



NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows:

Company
Expiration Date
Amount of Facility
Interest Rate (a)
Amount Drawn
as of
December 31, 2023
Letters of Credit Outstanding as of December 31, 2023
Entergy Arkansas
April 2024
$25 million (b)
7.29%
Entergy Arkansas
June 2028
$150 million (c)
6.58%
Entergy Louisiana
June 2028
$350 million (c)
6.71%
Entergy Mississippi
July 2025
$150 million
6.58%
Entergy New Orleans
June 2024
$25 million (c)
7.08%
Entergy Texas
June 2028
$150 million (c)
6.71%
$1.1 million

a.The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility.
b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023:
Company
Amount of Uncommitted Facility
Letter of Credit Fee
Letters of Credit Issued as of
December 31, 2023
(a) (b)
Entergy Arkansas
$25 million
0.78%
$5.8 million
Entergy Louisiana
$125 million
0.78%
$17.1 million
Entergy Mississippi
$65 million
0.78%
$20 million
Entergy New Orleans
$15 million
1.625%
$0.5 million
Entergy Texas
$80 million
1.250%
$76.5 million

a.As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.
b.As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

Authorized
Borrowings
(In Millions)
Entergy Arkansas
$250
$145
Entergy Louisiana
$450
$156
Entergy Mississippi
$200
$74
Entergy New Orleans
$150
$22
Entergy Texas
$200
$—
System Energy
$200
$12



NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025.
NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTERESTS

Note 6 to the financial statements is not applicable to Entergy Mississippi.

NOTE 7. COMMON EQUITY

Note 7 to the financial statements is not applicable to Entergy Mississippi.

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of
harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries.

Grand Gulf - Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)
System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.

Nelson Industrial Steam Company (Entergy Louisiana)

Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material.


NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by the Registrant Subsidiaries were as follows:

Liabilities as of December 31, 2022


Accretion
Change in
Cash Flow
Estimate
Liabilities as of December 31, 2023
(In Millions)
Entergy Arkansas
$1,472.7
$87.4
$—
$1,560.1
Entergy Louisiana
$1,736.8
$88.6
$10.8
$1,836.2
Entergy Mississippi
$7.8
$0.4
$—
$8.2
Entergy New Orleans
$—
$0.5
$4.1
$4.6
Entergy Texas
$11.1
$0.6
$—
$11.7
System Energy
$1,042.5
$41.7
$—
$1,084.2
Liabilities as
of December 31,
2021


Accretion
Change in
Cash Flow
Estimate


Spending
Dispositions
Liabilities as
of December 31,
2022
(In Millions)
Utility
Entergy Arkansas
$1,390.4
$82.3
$—
$—
$—
$1,472.7
Entergy Louisiana
$1,653.2
$84.1
$2.8
($3.3)
$—
$1,736.8
Entergy Mississippi
$10.3
$0.6
$—
($3.1)
$—
$7.8
Entergy New Orleans
$4.0
$0.1
$—
($4.1)
$—
$—
Entergy Texas
$8.5
$0.5
$2.1
$—
$—
$11.1
System Energy
$1,007.6
$40.2
($5.4)
$—
$—
$1,042.5
Coal Combustion Residuals

In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed.

In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit.


NOTE 10. LEASES

As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases.

Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to
renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy
New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$17,065
$16,906
$7,837
$1,912
$7,290
Finance lease cost:
Amortization of right-of-use assets
$3,633
$4,835
$2,227
$1,025
$1,786
Interest on lease liabilities
$545
$729
$973
$150
$284

Of the lease costs disclosed above, Entergy Mississippi had $1.1 million in short-term lease costs for the year ended December 31, 2023.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy
New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$15,435
$15,016
$7,510
$1,755
$5,624
Finance lease cost:
Amortization of right-of-use assets
$3,048
$4,259
$1,962
$906
$1,629
Interest on lease liabilities
$402
$592
$261
$134
$230

Of the lease costs disclosed above, Entergy Mississippi had $0.9 million in short-term lease costs for the year ended December 31, 2022.

The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
Operating leases
$61,718
$54,047
$25,470
$6,119
$21,321
Finance leases
$17,622
$21,438
$22,661
$4,779
$8,714
2022
Operating leases
$56,000
$46,137
$23,624
$5,906
$17,076
Finance leases
$13,493
$18,540
$8,578
$4,342
$8,094

The following lease-related liabilities are recorded within the Registrant Subsidiaries’ respective balance sheets at December 31, 2023:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$15,514
$14,771
$6,754
$1,681
$6,023
Finance leases
$3,743
$4,870
$3,059
$991
$1,865
Non-current liabilities:
Operating leases
$46,211
$39,282
$18,722
$4,377
$15,304
Finance leases
$13,879
$16,568
$19,602
$3,788
$6,849

The following lease-related liabilities are recorded within the Registrant Subsidiaries’ respective balance sheets at December 31, 2022:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$14,140
$13,554
$6,540
$1,650
$5,640
Finance leases
$2,985
$4,276
$1,974
$918
$1,654
Non-current liabilities:
Operating leases
$41,874
$32,588
$17,098
$4,217
$11,441
Finance leases
$10,508
$14,264
$6,604
$3,424
$6,440

The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted-average remaining lease terms:
Operating leases
4.62
4.60
5.34
6.38
4.44
Finance leases
5.57
5.40
17.82
5.73
5.49
Weighted-average discount rate:
Operating leases
4.04%
4.01%
4.08%
4.02%
4.43%
Finance leases
3.77%
3.85%
5.08%
3.69%
3.76%

The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted-average remaining lease terms:
Operating leases
4.55
4.26
5.31
6.08
3.84
Finance leases
5.32
5.27
5.15
5.72
5.67
Weighted-average discount rate:
Operating leases
3.43%
3.24%
3.52%
3.50%
3.63%
Finance leases
2.93%
3.15%
2.87%
3.04%
3.07%

Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows:

Operating Leases

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2024
$17,399
$16,539
$7,652
$1,867
$6,828
2025
15,716
13,908
6,846
1,442
5,892
2026
13,855
11,374
5,409
1,080
4,736
2027
10,587
8,493
4,105
704
2,834
2028
4,597
4,595
2,212
476
1,563
Years thereafter
4,598
4,035
2,421
1,376
1,672
Minimum lease payments
66,752
58,944
28,645
6,945
23,525
Less: amount representing interest
5,027
4,891
3,170
887
2,198
Present value of net minimum lease payments
$61,725
$54,053
$25,475
$6,058
$21,327

Finance Leases

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2024
$4,600
$5,692
$3,388
$1,148
$2,139
2025
4,179
5,037
3,093
1,016
1,975
2026
3,747
4,279
2,775
932
1,739
2027
3,088
3,389
2,322
796
1,413
2028
2,245
2,545
1,908
603
1,145
Years thereafter
2,918
3,199
23,562
812
1,222
Minimum lease payments
20,777
24,141
37,048
5,307
9,633
Less: amount representing interest
3,155
2,703
14,387
528
919
Present value of net minimum lease payments
$17,622
$21,438
$22,661
$4,779
$8,714

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases.


NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature.

The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating
the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)


The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$18,461
$24,716
$5,775
$1,955
$4,328
$5,749
Interest cost on projected benefit obligation
56,026
60,346
15,402
6,747
12,726
13,852
Expected return on assets
(70,574)
(75,757)
(19,423)
(8,798)
(16,641)
(17,585)
Recognized net loss
19,400
19,797
5,719
1,694
4,075
4,236
Settlement charges
26,137
40,437
12,242
2,080
11,230
6,375
Net pension cost
$49,450
$69,539
$19,715
$3,678
$15,718
$12,627
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain
($30,674)
($71,016)
($20,220)
($3,183)
($16,759)
($3,268)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(19,400)
(19,797)
(5,719)
(1,694)
(4,075)
(4,236)
Settlement charge
(26,137)
(40,437)
(12,242)
(2,080)
(11,230)
(6,375)
Total
($76,211)
($131,250)
($38,181)
($6,957)
($32,064)
($13,879)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
($26,761)
($61,711)
($18,466)
($3,279)
($16,346)
($1,252)

2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$25,210
$33,520
$8,043
$2,745
$5,999
$7,746
Interest cost on projected benefit obligation
45,378
49,330
12,979
5,491
10,729
11,286
Expected return on assets
(75,820)
(82,478)
(20,168)
(9,920)
(18,317)
(18,173)
Recognized net loss
43,597
41,711
12,594
4,787
9,013
10,938
Settlement charges
36,409
58,550
15,786
6,676
22,411
9,905
Net pension cost
$74,774
$100,633
$29,234
$9,779
$29,835
$21,702
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net (gain)/loss
$28,365
($15,604)
($4,743)
$525
$13,363
($7,063)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(43,597)
(41,711)
(12,594)
(4,787)
(9,013)
(10,938)
Settlement charge
(36,409)
(58,550)
(15,786)
(6,676)
(22,411)
(9,905)
Total
($51,641)
($115,865)
($33,123)
($10,938)
($18,061)
($27,906)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
$23,133
($15,232)
($3,889)
($1,159)
$11,774
($6,204)

2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$28,632
$38,271
$9,070
$3,038
$6,921
$8,851
Interest cost on projected benefit obligation
35,683
39,740
10,446
4,392
8,381
9,087
Expected return on assets
(78,368)
(89,821)
(22,407)
(10,598)
(21,158)
(19,254)
Recognized net loss
69,290
67,015
20,007
7,596
12,676
18,404
Settlement charges
37,682
61,945
16,710
5,431
11,797
12,260
Net pension cost
$92,919
$117,150
$33,826
$9,859
$18,617
$29,348
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain
($96,066)
($89,534)
($29,675)
($16,159)
($18,217)
($27,617)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(69,290)
(67,015)
(20,007)
(7,596)
(12,676)
(18,404)
Settlement charge
(37,682)
(61,945)
(16,710)
(5,431)
(11,797)
(12,260)
Total
($203,038)
($218,494)
($66,392)
($29,186)
($42,690)
($58,281)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
($110,119)
($101,344)
($32,566)
($19,327)
($24,073)
($28,933)

Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,168,098
$1,256,422
$320,994
$140,436
$265,565
$288,302
Service cost
18,461
24,716
5,775
1,955
4,328
5,749
Interest cost
56,026
60,346
15,402
6,747
12,726
13,852
Actuarial (gain)/loss
39,643
1,925
(328)
4,590
(1,416)
14,522
Benefits paid (a)
(164,643)
(170,126)
(45,901)
(19,778)
(41,219)
(35,867)
Balance at December 31
$1,117,585
$1,173,283
$295,942
$133,950
$239,984
$286,558
Change in Plan Assets
Fair value of assets at January 1
$961,178
$1,035,574
$265,736
$119,710
$226,417
$240,392
Actual return on plan assets
140,891
148,698
39,315
16,571
31,984
35,375
Employer contributions
54,468
44,565
21,110
1,420
5,314
15,543
Benefits paid (a)
(164,643)
(170,126)
(45,901)
(19,778)
(41,219)
(35,867)
Fair value of assets at December 31
$991,894
$1,058,711
$280,260
$117,923
$222,496
$255,443
Funded status
($125,691)
($114,572)
($15,682)
($16,027)
($17,488)
($31,115)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($125,691)
($114,572)
($15,682)
($16,027)
($17,488)
($31,115)
Amounts recognized as regulatory asset
Net loss
$485,113
$319,116
$102,208
$44,911
$63,665
$111,996
Amounts recognized as AOCI (before tax)
Net loss
$—
$13,296
$—
$—
$—
$—

a.Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy.
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,579,346
$1,736,396
$448,858
$195,380
$371,802
$394,794
Service cost
25,210
33,520
8,043
2,745
5,999
7,746
Interest cost
45,378
49,330
12,979
5,491
10,729
11,286
Actuarial gain
(280,691)
(357,572)
(88,303)
(40,462)
(65,795)
(81,504)
Benefits paid (a)
(201,145)
(205,252)
(60,583)
(22,718)
(57,170)
(44,020)
Balance at December 31
$1,168,098
$1,256,422
$320,994
$140,436
$265,565
$288,302
Change in Plan Assets
Fair value of assets at January 1
$1,302,588
$1,446,658
$356,424
$172,366
$341,915
$312,060
Actual return on plan assets
(233,236)
(259,490)
(63,392)
(31,067)
(60,841)
(56,267)
Employer contributions
92,971
53,658
33,287
1,129
2,513
28,619
Benefits paid (a)
(201,145)
(205,252)
(60,583)
(22,718)
(57,170)
(44,020)
Fair value of assets at December 31
$961,178
$1,035,574
$265,736
$119,710
$226,417
$240,392
Funded status
($206,920)
($220,848)
($55,258)
($20,726)
($39,148)
($47,910)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($206,920)
($220,848)
($55,258)
($20,726)
($39,148)
($47,910)
Amounts recognized as regulatory asset
Net loss
$561,323
$445,116
$140,389
$51,868
$95,729
$125,876
Amounts recognized as AOCI (before tax)
Net loss
$—
$18,546
$—
$—
$—
$—

a.Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy.

The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified
pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations.

Accumulated Pension Benefit Obligation

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows:

December 31,
2023
2022
(In Thousands)
Entergy Arkansas
$1,048,901
$1,008,152
Entergy Louisiana
$1,085,318
$1,146,561
Entergy Mississippi
$273,338
$292,596
Entergy New Orleans
$125,878
$128,499
Entergy Texas
$225,379
$245,428
System Energy
$267,432
$269,583

Other Postretirement Benefits

Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law.

Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf.
Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts.

Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI

Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$2,965
$3,379
$878
$235
$809
$754
Interest cost on APBO
8,002
8,931
2,170
1,160
2,597
1,726
Expected return on assets
(15,113)
(4,716)
(5,263)
(8,776)
(2,535)
Amortization of prior service cost/(credit)
2,096
(3,804)
(955)
(916)
(4,371)
(293)
Recognized net (gain)/loss
171
(7,057)
85
466
914
Net other postretirement benefits (income)/cost
($1,879)
$1,449
($2,538)
($4,318)
($8,827)
($348)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service credit for the period
$—
($4,434)
$—
$—
$—
$—
Net gain
(23,033)
(458)
(6,883)
(7,606)
(8,790)
(3,942)
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit/(cost)
(2,096)
3,804
955
916
4,371
293
Amortization of net gain/(loss)
(171)
7,057
(85)
(466)
(914)
Total
($25,300)
$5,969
($6,013)
($7,156)
($5,333)
($3,649)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
($27,179)
$7,418
($8,551)
($11,474)
($14,160)
($3,997)
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$4,457
$5,633
$1,354
$397
$1,322
$1,239
Interest cost on APBO
5,050
5,770
1,401
694
1,596
1,116
Expected return on assets
(17,930)
(5,575)
(5,997)
(10,273)
(3,162)
Amortization of prior service cost/(credit)
1,885
(4,630)
(1,772)
(916)
(4,371)
(319)
Recognized net (gain)/loss
873
(744)
222
(898)
648
121
Net other postretirement benefits (income)/cost
($5,665)
$6,029
($4,370)
($6,720)
($11,078)
($1,005)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
$273
$323
($1,300)
$—
$—
$141
Net (gain)/loss
12,894
(65,501)
6,629
17,334
22,323
1,208
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit/(cost)
(1,885)
4,630
1,772
916
4,371
319
Amortization of net gain/(loss)
(873)
744
(222)
898
(648)
(121)
Total
$10,409
($59,804)
$6,879
$19,148
$26,046
$1,547
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
$4,744
($53,775)
$2,509
$12,428
$14,968
$542

2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$4,135
$6,174
$1,448
$437
$1,384
$1,340
Interest cost on APBO
3,726
4,520
1,110
521
1,269
878
Expected return on assets
(18,020)
(5,536)
(5,750)
(10,192)
(3,156)
Amortization of prior service credit
(1,121)
(4,920)
(1,775)
(916)
(3,742)
(436)
Recognized net (gain)/loss
196
(364)
76
(712)
398
61
Net other postretirement benefits (income)/cost
($11,084)
$5,410
($4,677)
($6,420)
($10,883)
($1,313)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
($85)
$357
$—
$—
($3,776)
$69
Net (gain)/loss
9,956
(2,367)
(2,823)
(3,330)
939
210
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
1,121
4,920
1,775
916
3,742
436
Amortization of net gain/(loss)
(196)
364
(76)
712
(398)
(61)
Total
$10,796
$3,274
($1,124)
($1,702)
$507
$654
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
($288)
$8,684
($5,801)
($8,122)
($10,376)
($659)

Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet

Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$164,018
$183,126
$44,365
$23,971
$53,482
$35,274
Service cost
2,965
3,379
878
235
809
754
Interest cost
8,002
8,931
2,170
1,160
2,597
1,726
Plan amendments
(4,434)
Plan participant contributions
3,131
4,317
1,386
374
680
994
Actuarial (gain)/loss
(6,403)
(458)
(1,650)
(1,676)
337
(1,075)
Benefits paid
(15,759)
(24,768)
(5,815)
(2,384)
(6,299)
(3,908)
Medicare Part D subsidy received
33
46
10
5
11
13
Balance at December 31
$155,987
$170,139
$41,344
$21,685
$51,617
$33,778
Change in Plan Assets
Fair value of assets at January 1
$255,117
$—
$79,496
$91,140
$148,799
$42,434
Actual return on plan assets
31,743
9,949
11,193
17,903
5,402
Employer contributions
582
20,451
646
213
235
480
Plan participant contributions
3,131
4,317
1,386
374
680
994
Benefits paid
(15,759)
(24,768)
(5,815)
(2,384)
(6,299)
(3,908)
Fair value of assets at December 31
$274,814
$—
$85,662
$100,536
$161,318
$45,402
Funded status
$118,827
($170,139)
$44,318
$78,851
$109,701
$11,624
Amounts recognized in the balance sheet
Current liabilities
$—
($15,049)
$—
$—
$—
$—
Non-current liabilities
118,827
(155,090)
44,318
78,851
109,701
11,624
Total funded status
$118,827
($170,139)
$44,318
$78,851
$109,701
$11,624
Amounts recognized in regulatory asset
Prior service cost/(credit)
$4,983
$—
($2,682)
($1,982)
($11,790)
($496)
Net loss/(gain)
(17,980)
(4,815)
(5,843)
14,542
112
($12,997)
$—
($7,497)
($7,825)
$2,752
($384)
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($12,645)
$—
$—
$—
$—
Net gain
(75,709)
$—
($88,354)
$—
$—
$—
$—

2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$221,183
$253,031
$61,001
$31,866
$71,961
$47,875
Service cost
4,457
5,633
1,354
397
1,322
1,239
Interest cost
5,050
5,770
1,401
694
1,596
1,116
Plan amendments
273
323
(1,300)
141
Plan participant contributions
5,521
5,081
1,443
440
924
1,222
Actuarial gain
(54,923)
(65,501)
(14,465)
(6,867)
(16,291)
(10,679)
Benefits paid
(17,585)
(21,268)
(5,075)
(2,566)
(6,046)
(5,657)
Medicare Part D subsidy received
42
57
6
7
16
17
Balance at December 31
$164,018
$183,126
$44,365
$23,971
$53,482
$35,274
Change in Plan Assets
Fair value of assets at January 1
$315,495
$—
$97,888
$111,137
$182,285
$54,650
Actual return on plan assets
(49,887)
(15,519)
(18,204)
(28,341)
(8,725)
Employer contributions
1,573
16,187
759
333
(23)
944
Plan participant contributions
5,521
5,081
1,443
440
924
1,222
Benefits paid
(17,585)
(21,268)
(5,075)
(2,566)
(6,046)
(5,657)
Fair value of assets at December 31
$255,117
$—
$79,496
$91,140
$148,799
$42,434
Funded status
$91,099
($183,126)
$35,131
$67,169
$95,317
$7,160
Amounts recognized in the balance sheet
Current liabilities
$—
($15,356)
$—
$—
$—
$—
Non-current liabilities
91,099
(167,770)
35,131
67,169
95,317
7,160
Total funded status
$91,099
($183,126)
$35,131
$67,169
$95,317
$7,160
Amounts recognized in regulatory asset
Prior service cost/(credit)
$7,079
$—
($3,637)
($2,898)
($16,161)
($789)
Net loss
5,224
2,153
2,229
24,246
4,054
$12,303
$—
($1,484)
($669)
$8,085
$3,265
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($12,015)
$—
$—
$—
$—
Net gain
(82,308)
$—
($94,323)
$—
$—
$—
$—

The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022.

Non-Qualified Pension Plans

Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees.

The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$637
$99
$808
$132
$253
2022
$282
$102
$321
$114
$1,320
2021
$343
$307
$365
$30
$615

Included in the 2023 net periodic pension cost above are settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, related to the lump sum benefits paid out of
the plan. Included in the 2022 net periodic pension cost above are settlement charges of $1 thousand, $2 thousand, and $1 million for Entergy Louisiana, Entergy Mississippi, and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included in the 2021 net periodic pension cost above are settlement charges of $155 thousand and $172 thousand for Entergy Louisiana and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan.

The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$2,313
$2,574
$3,369
$1,034
$3,762
2022
$2,433
$1,197
$3,830
$1,024
$3,850

The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$1,935
$2,494
$3,187
$814
$3,701
2022
$2,192
$1,197
$3,594
$719
$3,776

The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022:

2023
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($276)
($308)
($474)
($106)
($448)
Non-current liabilities
(2,037)
(2,266)
(2,895)
(928)
(3,314)
Total funded status
($2,313)
($2,574)
($3,369)
($1,034)
($3,762)
Regulatory asset/(liability)
$857
$1,604
$1,303
$5
($2,526)
Accumulated other comprehensive income (before taxes)
$—
$67
$—
$—
$—

2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($234)
($184)
($214)
($32)
($448)
Non-current liabilities
(2,199)
(1,013)
(3,616)
(992)
(3,402)
Total funded status
($2,433)
($1,197)
($3,830)
($1,024)
($3,850)
Regulatory asset/(liability)
$512
$119
$1,291
$111
($2,615)
Accumulated other comprehensive income (before taxes)
$—
$5
$—
$—
$—

The non-qualified pension plans incurred a small actuarial loss during 2023 primarily as a result of liability losses due to differences in recent retirement and lump sum experience relative to actuarial assumptions. The non-qualified pension plans incurred a small actuarial gain during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by differences in recent retirement and lump sum experience relative to actuarial assumptions.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Plan II, and Bargaining Plan II exceeded the sum of the Plans’ service and interest cost, resulting in settlement costs during 2023, 2022, and 2021. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of Non-Bargaining Plan I and Bargaining Plan I and incurred settlement costs. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Qualified Pension and Other Postretirement Plans’ Assets

The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.

In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period.

The target asset allocation for pension adjusts dynamically based on the funded status of each plan within the trust. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets.

For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted-average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts.
Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2023 and 2022 and the target asset allocation and ranges for 2023 are as follows:

Pension Asset Allocation
Target
Range
Actual 2023
Actual 2022
Domestic Equity Securities
32%
26%
to
38%
33%
42%
International Equity Securities
17%
14%
to
20%
18%
22%
Intermediate Fixed Income Securities
8%
7%
to
9%
9%
11%
Long Duration Fixed Income Securities
43%
39%
to
47%
40%
22%
Other
—%
—%
to
10%
—%
3%

Postretirement Asset Allocation
Non-Taxable and Taxable
Target
Range
Actual 2023
Actual 2022
Domestic Equity Securities
25%
20%
to
30%
28%
25%
International Equity Securities
17%
12%
to
22%
17%
18%
Fixed Income Securities
58%
53%
to
63%
55%
57%
Other
—%
—%
to
5%
—%
—%

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers.

The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades.

The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used.

For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets.

Concentrations of Credit Risk

Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area, and individual security issuance. As of December 31, 2023, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefits plan assets.

Fair Value Measurements
Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are described below:

Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

- quoted prices for similar assets or liabilities in active markets;
- quoted prices for identical assets or liabilities in inactive markets;
- inputs other than quoted prices that are observable for the asset or liability; or
- inputs that are derived principally from or corroborated by observable market data by correlation or other means.

If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.

Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2023, and December 31, 2022, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.

Qualified Defined Benefit Pension Plan Trusts

2023
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$10,827
(b)
$—
$—
$10,827
Common
715,452
(b)
715,452
Common collective trusts (c)
2,066,247
Fixed income securities:
U.S. Government securities
1,085,231
(a)
1,085,231
Corporate debt instruments
924,904
(a)
924,904
Registered investment companies (e)
34,364
(d)
2,718
(d)
657,691
Other
774
(f)
78,883
(f)
79,657
Other:
Insurance company general account (unallocated contracts)
5,899
(g)
5,899
Total investments
$761,417
$2,097,635
$—
$5,545,908
Cash
1,488
Other pending transactions
(22,404)
Less: Other postretirement assets included in total investments
(64,391)
Total fair value of qualified pension assets
$5,460,601

2022
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$12,178
(b)
$—
$—
$12,178
Common
807,437
(b)
807,437
Common collective trusts (c)
2,516,688
Fixed income securities:
U.S. Government securities
673,348
(a)
673,348
Corporate debt instruments
525,184
(a)
525,184
Registered investment companies (e)
221,582
(d)
2,595
(d)
750,454
Other
15,395
(f)
15,395
Other:
Insurance company general account (unallocated contracts)
5,911
(g)
5,911
Total investments
$1,041,197
$1,222,433
$—
$5,306,595
Cash
10,601
Other pending transactions
(13,813)
Less: Other postretirement assets included in total investments
(61,285)
Total fair value of qualified pension assets
$5,242,098

Other Postretirement Trusts

2023
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$276,560
Fixed income securities:
U.S. Government securities
$80,219
(b)
$84,521
(a)
$—
164,740
Corporate debt instruments
106,523
(a)
106,523
Registered investment companies
548
(d)
548
Other
57,511
(f)
57,511
Total investments
$80,767
$248,555
$—
$605,882
Other pending transactions
2,868
Plus: Other postretirement assets included in the investments of the qualified pension trust
64,391
Total fair value of other postretirement assets
$673,141

2022
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$241,676
Fixed income securities:
U.S. Government securities
$69,503
(b)
$78,436
(a)
$—
147,939
Corporate debt instruments
113,273
(a)
113,273
Registered investment companies
3,016
(d)
3,016
Other
56,149
(f)
56,149
Total investments
$72,519
$247,858
$—
$562,053
Other pending transactions
486
Plus: Other postretirement assets included in the investments of the qualified pension trust
61,285
Total fair value of other postretirement assets
$623,824

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.
b.Common stocks, preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.
c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities valued at the daily closing price as reported by the fund. These funds are required to publish their daily net asset value and to transact at that price. The money market mutual funds held by the trusts are deemed to be actively traded. Certain registered investment companies are recorded at contract value, which approximates fair value.
e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes.
g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Estimated Future Benefit Payments

Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefits obligations at December 31, 2023, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows:

Estimated Future Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2024
$90,682
$95,706
$25,534
$11,300
$21,807
$24,163
2025
$89,113
$92,420
$24,816
$10,799
$21,019
$22,053
2026
$88,427
$92,499
$25,210
$10,910
$21,268
$21,612
2027
$87,845
$91,485
$24,686
$10,566
$20,407
$22,665
2028
$87,719
$91,450
$24,147
$10,458
$20,074
$22,107
2029 - 2033
$429,882
$444,131
$115,629
$48,870
$92,182
$109,712

Estimated Future Non-Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Year(s)
2024
$276
$308
$474
$106
$448
2025
$474
$301
$547
$143
$423
2026
$160
$288
$461
$139
$445
2027
$149
$265
$642
$224
$395
2028
$288
$270
$395
$141
$369
2029 - 2033
$938
$941
$1,326
$529
$1,524

Estimated Future Other Postretirement Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2024
$13,697
$15,049
$3,521
$2,200
$5,187
$2,811
2025
$12,913
$14,380
$3,386
$2,086
$4,874
$2,668
2026
$12,342
$13,676
$3,256
$1,942
$4,436
$2,434
2027
$11,767
$13,037
$3,126
$1,785
$4,215
$2,320
2028
$11,424
$12,348
$3,121
$1,640
$3,937
$2,266
2029 - 2033
$54,789
$57,264
$14,563
$7,297
$17,857
$11,270

Contributions

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024:

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Pension Contributions
$55,112
$48,401
$14,980
$4,931
$8,272
$16,650
Other Postretirement Contributions
$529
$15,049
$178
$205
$156
$34

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefits APBO as of December 31, 2023 and 2022 were as follows:

2023
2022
Weighted-average discount rate:
Qualified pension
5.02% - 5.10%
Blended 5.06%
5.21% - 5.27%
Blended 5.24%
Other postretirement
5.01%
5.20%
Non-qualified pension
4.68%
4.98%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
Interest crediting rate
4.00%
4.00%
Assumed health care trend rate:
Pre-65
6.95%
6.65%
Post-65
7.88%
7.50%
Ultimate health care cost trend rate
4.75%
4.75%
Year ultimate health care cost trend rate is reached and beyond:
Pre-65
2032
2032
Post-65
2032
2032

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefits costs for 2023, 2022, and 2021 were as follows:

2023
2022
2021
Weighted-average discount rate:
Qualified pension:
Service cost
5.26%
3.07%
2.81%
Interest cost
5.16%
2.49%
2.08%
Other postretirement:
Service cost
5.00%
3.20%
2.98%
Interest cost
5.09%
2.31%
1.86%
Non-qualified pension:
Service cost
5.31%
4.94%
1.48%
Interest cost
5.30%
5.03%
2.14%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
3.98% - 4.40%
Expected long-term rate of return on plan assets:
Pension assets
7.00%
6.75%
6.75%
Other postretirement non-taxable assets
6.00% - 7.00%
5.75% - 6.75%
6.00% - 6.75%
Other postretirement taxable assets
5.25%
4.75%
5.00%
Assumed health care trend rate:
Pre-65
6.65%
5.65%
5.87%
Post-65
7.50%
5.90%
6.31%
Ultimate health care cost trend rate
4.75%
4.75%
4.75%
Year ultimate health care cost trend rate is reached and beyond:
Pre-65
2032
2032
2030
Post-65
2032
2032
2028

With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2023 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2023 other postretirement benefits APBO. With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 other postretirement benefits APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (Savings Plan VI) (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (Savings Plan VII) (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries. Effective
December 31, 2023, employees participating in Savings Plan VI and Savings Plan VII were transferred into the System Savings Plan when Savings Plan VI and Savings Plan VII merged into the System Savings Plan.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’ basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows:



Year
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$5,866
$7,757
$3,534
$1,383
$3,380
2022
$5,124
$7,138
$3,194
$1,223
$2,938
2021
$4,820
$6,678
$3,045
$1,140
$2,699


NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis.


NOTE 14. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Sunflower Solar

In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy
Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives
Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022.

The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and
are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
(In Millions)
2023
Assets:
Financial transmission rights
Prepayments and other
$6.0
$—
$6.0
Entergy Arkansas
Financial transmission rights
Prepayments and other
$9.8
$—
$9.8
Entergy Louisiana
Financial transmission rights
Prepayments and other
$1.4
$—
$1.4
Entergy Mississippi
Financial transmission rights
Prepayments and other
$1.1
$—
$1.1
Entergy New Orleans
Financial transmission rights
Prepayments and other
$2.7
($0.3)
$2.4
Entergy Texas
Liabilities:
Natural gas swaps and options
Other current liabilities
$0.4
$—
$0.4
Entergy Louisiana
Natural gas swaps
Other current liabilities
$10.1
$—
$10.1
Entergy Mississippi
Natural gas swaps
Other current liabilities
$0.6
$—
$0.6
Entergy New Orleans

Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
(In Millions)
2022
Assets:
Natural gas swaps and options
Prepayments and other
$13.1
$—
$13.1
Entergy Louisiana
Natural gas swaps and options
Other deferred debits and other assets
$3.4
$—
$3.4
Entergy Louisiana
Financial transmission rights
Prepayments and other
$10.3
$—
$10.3
Entergy Arkansas
Financial transmission rights
Prepayments and other
$7.7
($0.4)
$7.3
Entergy Louisiana
Financial transmission rights
Prepayments and other
$0.6
$—
$0.6
Entergy Mississippi
Financial transmission rights
Prepayments and other
$0.8
$—
$0.8
Entergy New Orleans
Financial transmission rights
Prepayments and other
$1.2
($1.1)
$0.1
Entergy Texas
Liabilities:
Natural gas swaps
Other current liabilities
$24.0
$—
$24.0
Entergy Mississippi
Natural gas swaps
Other current liabilities
$1.5
$—
$1.5
Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities
b.Represents the netting of fair value balances with the same counterparty
c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
d.As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows:

Instrument
Income Statement Location
Amount of gain (loss) recorded in the income statement
Registrant
(In Millions)
2023
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
($8.4)
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($42.9)
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($3.0)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$25.8
(b)
Entergy Arkansas
Financial transmission rights
Purchased power expense
$60.4
(b)
Entergy Louisiana
Financial transmission rights
Purchased power expense
$13.7
(b)
Entergy Mississippi
Financial transmission rights
Purchased power expense
$6.4
(b)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$17.3
(b)
Entergy Texas
2022
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
$21.4
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
$53.6
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($1.2)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$106.5
(b)
Entergy Arkansas
Financial transmission rights
Purchased power expense
$48.5
(b)
Entergy Louisiana
Financial transmission rights
Purchased power expense
$10.4
(b)
Entergy Mississippi
Financial transmission rights
Purchased power expense
$3.7
(b)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$6.3
(b)
Entergy Texas
2021
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
$12.6
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
$19.8
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($0.1)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$42.6
(b)
Entergy Arkansas
Financial transmission rights
Purchased power expense
$31.6
(b)
Entergy Louisiana
Financial transmission rights
Purchased power expense
$11.3
(b)
Entergy Mississippi
Financial transmission rights
Purchased power expense
$4.3
(b)
Entergy New Orleans
Financial transmission rights
Purchased power expense
$85.9
(b)
Entergy Texas

a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.
b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:
Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

quoted prices for similar assets or liabilities in active markets;
quoted prices for identical assets or liabilities in inactive markets;
inputs other than quoted prices that are observable for the asset or liability; or
inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights.

As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting.
The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer.

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Mississippi
2023
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Temporary cash investments
$6.6
$—
$—
$6.6
Storm reserve escrow account
0.7
0.7
Financial transmission rights
1.4
1.4
$7.3
$—
$1.4
$8.7
Liabilities:
Gas hedge contracts
$10.1
$—
$—
$10.1
2022
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Temporary cash investments
$17.0
$—
$—
$17.0
Storm reserve escrow account
33.5
33.5
Financial transmission rights
0.6
0.6
$50.5
$—
$0.6
$51.1
Liabilities:
Gas hedge contracts
$24.0
$—
$—
$24.0

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023.

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2023
$10.3
$7.3
$0.6
$0.8
$0.1
Issuances of financial transmission rights
20.6
18.1
1.3
1.4
0.2
Gains (losses) included as a regulatory liability/asset
0.9
44.8
13.2
5.3
19.4
Settlements
(25.8)
(60.4)
(13.7)
(6.4)
(17.3)
Balance as of December 31, 2023
$6.0
$9.8
$1.4
$1.1
$2.4

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022.

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2022
$2.3
$0.6
$0.3
$0.1
$0.8
Issuances of financial transmission rights
5.4
5.3
0.8
0.8
3.9
Gains (losses) included as a regulatory liability/asset
109.1
49.9
9.9
3.6
1.7
Settlements
(106.5)
(48.5)
(10.4)
(3.7)
(6.3)
Balance as of December 31, 2022
$10.3
$7.3
$0.6
$0.8
$0.1


NOTE 16. DECOMMISSIONING TRUST FUNDS

Note 16 to the financial statements is not applicable to Entergy Mississippi.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2023
$125.2
$317.6
$1.0
$—
$0.7
$588.4
2022
$127.5
$354.0
$1.0
$—
$18.9
$658.8
2021
$109.8
$289.9
$1.4
$—
$64.3
$545.6

Intercompany Operating Expenses

Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2023
$585.8
$719.8
$345.2
$302.5
$316.8
$179.0
2022
$617.4
$770.2
$356.1
$341.7
$321.4
$215.0
2021
$559.7
$755.2
$299.8
$287.8
$275.0
$190.8

Intercompany Interest and Investment Income
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2023
$0.7
$303.2
$0.2
$1.0
$1.8
$0.6
2022
$0.1
$186.1
$0.1
$0.1
$0.3
$0.3
2021
$—
$127.6
$—
$—
$—
$—


NOTE 19. SUBSEQUENT EVENTS

Management has evaluated the impact of events occurring after December 31, 2023 up to February 23, 2024, the date that Entergy Mississippi's U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through April 15, 2024. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
197,569,752
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
193,256,754
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
6,731,611,053
6,731,611,053
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
(a)
35,609,492
35,609,492
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
455,394,493
455,394,493
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
7,222,615,038
7,222,615,038
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
220,455
220,455
11
ConstructionWorkInProgress
Construction Work in Progress
157,119,085
157,119,085
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
83,828,315
83,828,315
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
7,463,782,893
7,463,782,893
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
(b)
2,155,897,819
2,155,897,819
15
UtilityPlantNet
Net Utility Plant (13 less 14)
5,307,885,074
5,307,885,074
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
1,867,945,386
1,867,945,386
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
(c)
264,825,831
264,825,831
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
2,132,771,217
2,132,771,217
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
6,808
6,808
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
6,808
6,808
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
23,119,794
23,119,794
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
(d)
2,155,897,819
2,155,897,819


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases
Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $186,178,032.
(c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService
Includes accumulated provision for amortization of intangible assets.
(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $186,178,032.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
370,364,640
38,874,562
288,512
408,950,690
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
370,364,640
38,874,562
288,512
408,950,690
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
2,270,414
268,683
2,001,731
9
(311) Structures and Improvements
66,401,626
608,452
12,665,036
54,345,042
10
(312) Boiler Plant Equipment
313,359,129
1,325,953
35,894,768
278,790,314
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
143,642,428
1,791,114
39,189,332
106,244,210
13
(315) Accessory Electric Equipment
48,492,458
214,335
10,411,673
38,295,120
14
(316) Misc. Power Plant Equipment
11,023,721
192,382
3,224,881
7,991,222
15
(317) Asset Retirement Costs for Steam Production
2,008,212
173,393
1,834,819
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
587,197,988
4,132,236
101,827,766
489,502,458
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
4,253,086
4,253,086
38
(341) Structures and Improvements
332,386,059
878,981
322,274
332,942,766
39
(342) Fuel Holders, Products, and Accessories
8,645,077
8,645,077
40
(343) Prime Movers
351,009,663
10,739,800
3,588,635
14,575,720
372,736,548
41
(344) Generators
235,615,546
1,026,184
17,305
14,575,720
222,048,705
42
(345) Accessory Electric Equipment
47,407,945
34,333
332,617
47,109,661
43
(346) Misc. Power Plant Equipment
8,066,607
41,177
8,107,784
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
987,383,983
12,720,475
4,260,831
995,843,627
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
1,574,581,971
16,852,711
106,088,597
1,485,346,085
47
3. Transmission Plant
48
(350) Land and Land Rights
111,283,700
206,150
111,489,850
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
73,352,562
8,760,137
10,099
82,102,600
50
(353) Station Equipment
762,857,607
32,079,437
4,359,360
790,577,684
51
(354) Towers and Fixtures
60,681,280
799
60,680,481
52
(355) Poles and Fixtures
506,812,463
21,048,925
515,705
527,345,683
53
(356) Overhead Conductors and Devices
357,233,061
18,128,721
673,534
374,688,248
54
(357) Underground Conduit
1,311
1,311
55
(358) Underground Conductors and Devices
6,310
6,310
56
(359) Roads and Trails
57
(359.1) Asset Retirement Costs for Transmission Plant
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
1,872,228,294
80,223,370
5,559,497
1,946,892,167
59
4. Distribution Plant
60
(360) Land and Land Rights
24,417,818
9,130,837
33,548,655
61
(361) Structures and Improvements
25,033,092
9,207,436
16,405
34,224,123
62
(362) Station Equipment
431,351,522
56,359,442
1,669,911
486,041,053
63
(363) Energy Storage Equipment – Distribution
64
(364) Poles, Towers, and Fixtures
450,548,415
60,312,114
12,251,253
498,609,276
65
(365) Overhead Conductors and Devices
543,660,900
51,495,882
12,217,132
582,939,650
66
(366) Underground Conduit
55,429,001
6,166,920
193,812
61,402,109
67
(367) Underground Conductors and Devices
113,157,445
11,722,470
1,863,661
123,016,254
68
(368) Line Transformers
662,468,772
79,571,396
11,541,034
730,499,134
69
(369) Services
193,668,964
6,826,666
550,443
199,945,187
70
(370) Meters
146,097,619
16,042,238
295,017
2,418,755
164,263,595
71
(371) Installations on Customer Premises
39,212,407
4,375,528
11,993,743
55,581,678
72
(372) Leased Property on Customer Premises
73
(373) Street Lighting and Signal Systems
94,920,381
12,588,719
5,923,924
101,585,176
74
(374) Asset Retirement Costs for Distribution Plant
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
2,779,966,336
323,799,648
34,528,849
2,418,755
3,071,655,890
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
7,835,243
7,835,243
87
(390) Structures and Improvements
134,042,092
25,324,598
115,797
159,250,893
88
(391) Office Furniture and Equipment
19,450,103
4,276,466
2,130,243
21,596,326
89
(392) Transportation Equipment
261,640
261,640
90
(393) Stores Equipment
12,348
17,969
30,317
91
(394) Tools, Shop and Garage Equipment
8,839,055
2,813,580
11,652,635
92
(395) Laboratory Equipment
4,412,313
4,412,313
93
(396) Power Operated Equipment
64,407
64,407
94
(397) Communication Equipment
57,431,703
8,594,099
66,025,802
95
(398) Miscellaneous Equipment
2,524,003
507,135
3,031,138
96
SUBTOTAL (Enter Total of lines 86 thru 95)
234,872,907
41,533,847
115,797
2,130,243
274,160,714
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
234,872,907
41,533,847
115,797
2,130,243
274,160,714
100
TOTAL (Accounts 101 and 106)
6,832,014,148
501,284,138
146,292,740
7,187,005,546
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
6,832,014,148
501,284,138
146,292,740
7,187,005,546


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Land and Land Rights Under $250,000
205,522
3
21 Other Property:
22
Other Property Under $250,000
14,933
47 TOTAL
220,455


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
*** DESIGN HOLD*** SOUTHAVEN - CITY
107,899
2
2020 - RANKIN - AIRPORT - 6A04 - 55
364,259
3
2020 - SOUTHAVEN - PLUM POINT - CHU
446,420
4
2020 Planning CL20-005V New Build N
245,239
5
2020 Planning CL20-005V Rep A1, RRE
406,457
6
2021-GRENADA-ENID 2B01-MDOT BRIDGE
622,154
7
2022 Woodrow Wilson Relocation
182,060
8
2022-GRENADA-MILWAUKEE TOOL PART 3
1,350,464
9
2022-Grenada-S Archie Jackson Rd-Mi
784,149
10
2022-Part 1-UG to Repl Ohead Hoy Rd
280,063
11
2022-Part 2-UG to Repl O'head Hoy R
549,876
12
2022-Part 3-UG to Repl O'Head Hoy R
338,021
13
2023-Madison-Canton-Fac Relocation
139,910
14
2023-Madison-Replace UG along 463 i
1,408,274
15
Baird, Baird Rd, Mathew Miller Irri
164,700
16
BROOKHAVEN-HWY 51-CITY OF BROOKHAVE
165,012
17
Byhalia Distribution Scoping
103,870
18
CARTHAGE-CITY OF CARTHAGE LED CONVE
116,292
19
CL21-002V Clinton Tinnin MT02 Long
163,129
20
Downtown Jackson - Replace 1500 KVA
166,121
21
FC21M053 - FOCUS - FA05 - 55F0575
104,839
22
FLOWOOD-KELLI FOSTER-LES MAISON PHA
162,012
23
GM-Vicksburg SE Guild 5F02-N7, N8,
1,205,973
24
GM-Vicksburg SE Guild 5F03-N6, FSW1
3,693,336
25
GM-Vicksburg SE Guild 5F03-N7, N8,
232,926
26
GM-Vicksburg SE Guild 5F03-R8 part
434,992
27
Lake Cormorant-Saint Brigid Subdivi
183,761
28
Madison 115kV Second Xfmr T&D Proje
434,035
29
Mannsdale T&D D-Scoping
484,442
30
MS FEEDER INVESTMENT, 2023, CLINTON
112,151
31
MS FEEDER INVESTMENT, 2023, UTICA,
3,211,847
32
MS FEEDER INVESTMENT, 2024, CLINTON
132,521
33
PELAHATCHIE - INDUSTRIAL DR - MENAS
140,405
34
Pine Tree - 1Y04 - Hwy 51
321,466
35
Pine Tree - 1Y05 & 1Y01 Tie
195,107
36
Pine Tree - 1Y05 I-55 Crossing
139,044
37
Pine Tree Substation T&D D-Scoping
864,107
38
PSK405-EML-Grenada Industrial Park
372,944
39
Relocate Facilities W Capitol St
645,179
40
RK20-010V Magee 7N01 Scoping
537,482
41
SE21-002V Senatobia Scoping
228,951
42
SLI JOB-- ROBINSONVILLE-1001 SCHULZ
106,160
43
SLI JOB-PELAHATCHIE - INDUSTRIAL DR
254,162
44
SOUTHAVEN - CITY WIDE LED CONVERSIO
333,794
45
STREET LIGHT TECHNICAL DESIGN-MCCOM
262,072
46
T&D - Madison Substation - Feeder-M
1,121,130
47
UPIC-Flowood-E. Metro Pkwy-Flowood
104,890
48
UPIC-HORN LAKE-WILLOW OAK DR-WILLOW
113,384
49
UPIC-Jackson-Livingston Rd-VLP, LLC
105,949
50
OTHER DISTRIBUTION LINES PLANT
4,786,139
51
2022 MISO Predictive Analytics
439,306
52
Accr Prx Code-Dist Cap EML
269,519
53
Broadcom Licenses - 2023
298,589
54
Clinton KAST Center Training Equipm
346,506
55
CRM Expansion
308,342
56
CVO - Cleveland SC Roofing (Storm)
114,230
57
Digital LIHEAP
741,137
58
Distribution Resiliency Plan
596,803
59
EMI: Camlin Pilot Franklin EHV
395,000
60
EML Public EV Charging Pilot
209,792
61
EML: Camlin Pilot - Baxter Wilson
296,250
62
eMobility Digital Tool WO
123,145
63
Grant Writing Costs - EML
253,567
64
IBM MRO IO Entergy Interface
216,618
65
IEDMS/ESNET Software Upgrade
515,644
66
Jackson Call Ctr Task Chairs
129,560
67
Miss. Signage Rebranding Costs
534,605
68
P2R Upgrade 2022-23
649,102
69
PGen Smart Procedures
366,760
70
PWTHR IT Systems
173,405
71
RPC Equipment Upgrade - Software
362,583
72
SW-Facilities Ratings WS-NERC Rep
534,977
73
Unbilled Revenue Accrual (Phase 2)
228,595
74
Video Management Solution Project
275,266
75
OTHER GENERAL & INTANGIBLE PLANT
1,069,695
76
A1A - GE LTSA Budget Cap 2020-2024
19,525,162
77
CO1 - Choctaw Emergency Generator
1,253,699
78
CO1 LTSA Capitalization CT 101
5,873,878
79
CO1 LTSA Capitalization- CT-201
255,419
80
CO1 LTSA Capitalization- CT-301
255,419
81
EMI - Delta Solar
1,150,229
82
EML - Penton Solar
1,407,473
83
HN1 - Hinds LTSA Capital
16,563,650
84
SPO EML SunflowerTaxEquityPartneshp
344,659
85
OTHER PRODUCTION PLANT
141,801
86
Batesville: Replace HV breaker J048
476,349
87
Baxter Wilson install new station s
746,964
88
Beech Grove: Scope, Design, Enginee
1,715,574
89
Belzoni: Install circuit switchers,
821,655
90
Build Pine Tree 230/12.47kV Sub
7,610,534
91
Byhalia 230-13.8kV Phase 1 Expand L
100,315
92
Catlett Road - Expand 230kV Substat
995,270
93
Charleston: Install Transformer and
215,819
94
Cleveland South: Install circuit sw
597,056
95
Crenshaw:  Add Circuit Switcher
281,726
96
Delta Steam Replace Capacitor Bank
427,145
97
Drew: Add circuit switchers, replac
981,601
98
Dundee 115kV SS Solar J1440 Scoping
193,819
99
Durant: Add circuit switchers, repl
657,086
100
EMI: Camlin Pilot (Freeport)
318,507
101
EMI: Camlin Pilot (Gerald Andrus)
106,169
102
EMI: Camlin Pilot (Grenada S)
106,169
103
EMI: Camlin Pilot (Lakeover)
637,014
104
EMI: Camlin Pilot (Ray Braswell)
212,338
105
EML: 115-13.8kV | 20MVA LTC
1,154,418
106
EML: 115-13.8kV | 50MVA LTC
980,982
107
EML: 13.8kV | 1.25MVA Regulator
283,906
108
EML: 13.8kV | 2.667MVA Spare Regs
644,667
109
EML: 230-13.8kV | 67MVA Incremental
606,339
110
EML: Camlin Mon S Grenada AT1
220,189
111
Forest Hill: Replace Main breakers
1,175,647
112
Grand Gulf: Replace East & West bus
148,792
113
Greenwood:  Replace XFMR J6825
415,076
114
Grenada Industrial 115kV Substation
2,222,788
115
Grenada: Add circuit switchers, rep
471,902
116
Horn Lake:  Transformer Life Extens
256,420
117
Indianola: Replace Control House &
1,216,504
118
Jackson South: Replace 230kV bus di
1,670,816
119
Leland: Replace breaker 3G05 and ad
239,650
120
Magee: Replace breaker J5820 & J582
377,081
121
Mannsdale 230kV Substation
3,220,715
122
Mendenhall: Replace transformer J49
434,459
123
Midnight: rpl ABS J0348 & Steel Bus
179,598
124
Midnight: rpl Oil Pump on J0346
123,026
125
Natchez S:  Replace J0855 XFMR
455,995
126
New Endris 230kV Swtiching Station
260,877
127
Pelahatchie: Replace capacitor bank
236,839
128
Pickens: Replace 4 ea. HV Breakers
533,060
129
Round Lake - Indianola Remote End
108,942
130
Round Lake S.S.-J1294-Intrcnt
190,133
131
Spencer Potash: Replace Main Breake
203,795
132
Tillatoba: Replace Breaker J2520 &
126,983
133
Vicksburg S:  Replace XFMR
799,554
134
Virliila - New 230kV Substation
8,040,162
135
Webb 115kV-J908 Intercon AddBrks NU
875,084
136
Webb:  Replace J3094 LAB
213,026
137
Webb115kV-J908 IntercnAddBrkrs-TOIF
474,992
138
Winona: Replace Storm Damages
3,632,624
139
Wolf Creek - Add 500kV Breaker
450,603
140
Yazoo City SW St:  Rpl XFMR
1,438,885
141
OTHER TRANSMISSION & DISTRIBUTION SUBS
1,300,786
142
Bowling Green - Durant 115kV CAP
155,593
143
C6ML300043: Horn Lake - Greenbrook
366,787
144
C6ML300045: Canton - S. Canton 230k
998,982
145
C6ML300079: Norrell - Tinnin Rd 230
1,086,904
146
C6ML300085: North Greenville - Stri
657,705
147
C6ML300087: North Greenville - Stri
599,672
148
C6ML300089: James Rd - Hazlehurst 1
413,529
149
C6ML300090: Copiah SS - Hazlehurst
245,231
150
C6ML300092: Canton - Pickens 230kV
992,113
151
C6ML300106: Rolling Fork - Onward 1
773,823
152
C6ML300107: Rolling Fork - Onward 1
677,160
153
C6ML300112: Pelahatchie - Rankin 11
269,170
154
C6ML300113: Flowers - Tinsley 115kV
141,148
155
C6ML300116: Delta SWYD - Cleveland/
130,487
156
C6ML300118: Onward - Redwood 115kV
121,321
157
Church Rd-Getwell 230kV T-Line
3,645,370
158
E. Vicksburg-E. Vicksburg 115kV CAP
134,425
159
Franklin-GGNS 500Kv Phase Swa
993,525
160
Getwell-Twinkletown 230kV Cut-In
1,426,606
161
Greenville TCEPA - Arcola 115kV CAP
261,030
162
Greenville-SE Greenville115kV LnUpr
1,276,760
163
Greenwood-Itta Bena 115Kv Cut-In
425,984
164
Grenada Ind-Grenada S 115kV Cut-In
101,571
165
Indianola - Tillatoba 230kV CAP
177,935
166
Lakeover-Hinds 230kV CAP
322,880
167
MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb)
606,222
168
MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)
147,607
169
Pelahatchie - Rankin 115kV CAP
189,435
170
Tillatoba-Grenada Ind 115kV Cut-In
102,342
171
OTHER TRANSMISSION LINES PLANT
493,219
172
UNDISTRIBUTED OVERHEADS:
1,248,170
43
Total
157,119,085


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
1,845,542,487
1,845,535,679
6,808
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
226,552,214
(a)
226,552,214
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
35,671
35,671
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
13,555
(b)
13,555
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
226,601,440
226,601,440
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
146,292,740
146,292,740
13
CostOfRemovalOfPlant
Cost of Removal
62,652,147
62,652,147
14
SalvageValueOfRetiredPlant
Salvage (Credit)
4,479,835
4,479,835
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
204,465,052
204,465,052
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
273,319
(c)
273,319
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
1,867,952,194
1,867,945,386
6,808
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
317,894,339
317,891,954
2,385
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
399,600,300
399,600,300
25
AccumulatedDepreciationTransmission
Transmission
498,082,177
498,077,754
4,423
26
AccumulatedDepreciationDistribution
Distribution
593,792,647
593,792,647
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
58,582,731
58,582,731
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
1,867,952,194
1,867,945,386
6,808


FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments
Excludes service company depreciation allocations of $3,809,288 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated reserves.
(b) Concept: OtherAccounts
Includes depreciation on Gerald Andrus pipelines and Independence, which is accounted for as fuel expense.
(c) Concept: OtherAdjustmentsToAccumulatedDepreciation
Loss on sale of land $268,683 
AMI: asset transfer 4,636 
Total $273,319 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
EMI New Nuclear, LLC - Subsidiary Company Subheading
09/18/2008
2
EMI New Nuclear, LLC - Capital Contribution
95,612,254
10,047,323
105,659,577
3
EMI New Nuclear, LLC - Unappropriated Undistributed Subsidiary Earnings
209,811
4,613,522
4,403,711
4
EMI New Nuclear, LLC - Subtotal
95,822,065
4,613,522
10,047,323
101,255,866
5
Mississippi Power & Light Co. - Subsidiary Company Subheading
6
Mississippi Power & Light Co. - Capital Contribution
517
517
7
Mississippi Power & Light Co. - Unappropriated Undistributed Subsidiary Earnings
275
275
8
Mississippi Power & Light Co. - Subtotal
242
242
42
Total Cost of Account 123.1 $
Total
95,822,307
4,613,522
10,047,323
101,256,108


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
15,537,354
16,188,254
2
Fuel Stock Expenses Undistributed (Account 152)
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
(a)
63,854,011
(b)
82,702,416
Electric
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
12,888,585
5,592,842
Electric
8
Transmission Plant (Estimated)
55,766
Electric
9
Distribution Plant (Estimated)
3,375,013
1,590,200
Electric
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
80,173,375
89,885,458
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
4,172,529
5,640,795
17
18
19
20
TOTAL Materials and Supplies
99,883,258
111,714,507


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
BEG OF YEAR
Production (estimated) $28,303,614 
Transmission (estimated) 11,659,903 
Distribution (estimated) 23,890,494 
Total Assigned to Construction (estimated) $63,854,011 
(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
 END OF YEAR
Production (estimated) $34,210,027 
Transmission (estimated) 10,713,143 
Distribution (estimated) 37,779,246 
Total Assigned to Construction (estimated) $82,702,416 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
176,812
176,812
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
15,931
15,930
15,930
15,930
(a)
446,047
509,768
0
5
Returned by EPA
6
7
8
Purchases/Transfers:
75
75
9
10
11
12
13
14
15
Total
75
75
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
Compliance Deduction
3,238
3,238
23
24
25
26
27
28
Total
3,238
3,238
29
Balance-End of Year
189,580
15,930
15,930
15,930
446,047
683,417
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2027 through 2054.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
1,738
10,807
1,738
10,807
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
2,363
2,313
2,313
2,313
(a)
4,626
13,928
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
1,292
3,401
1,292
3,401
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
2,809
7,406
2,313
2,313
2,313
4,626
14,374
7,406
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2027 through 2028.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20 TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Total
21
Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
Total
40 Grand Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022
4,011,369
356,566
3,654,803
2
Vegetation Management Rider Under-Recovery MPSC Docket No. 2018-UN-205
5,464,532
5,464,532
3
Asset Retirement Obligation - Fossil
5,658,890
350,966
6,009,856
4
Asset Retirement Obligation - Coal
649,377
116,608
765,985
5
Defined Benefit Pension & Other Post Retirement Plans
145,494,254
633,025
37,686,039
108,441,240
6
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020
1,646,286
191,799
1,454,487
7
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021
10,733,899
1,262,812
9,471,087
8
Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020
15,684,652
4,826,047
10,858,605
9
Electric Deferred Fuel Under-Recovery
143,210,730
143,210,730
10
Energy Efficiency Rider Under-Recovery
23,213,599
12,758,452
35,972,051
11
Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39
809,624
100,893
910,517
12
Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 - Amort pd Aug 2022 thru June 2023
16,975,276
16,975,276
13
Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132
31,363,365
8,517,444
39,880,809
14
Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620
20,164,570
20,164,570
15
Unit Power Cost Recovery Rider Under-Recovery MPSC Docket No. 2014-UN-132
6,420,161
10,005,310
16,425,471
16
COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022
9,849,236
9,849,236
17
Income Taxes
25,568,247
4,497,787
30,066,034
18
Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205
18,200,000
2,079,783
11,110,149
9,169,634
19
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022
7,867,084
773,812
7,093,272
20
Derivative Instruments and Hedging Activities
24,003,048
13,857,769
10,145,279
21
Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022
3,156,141
3,156,141
22
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 135 months beg April 2023
6,600,251
426,213
6,174,038
23
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 139 months beg April 2023
4,415,756
255,432
4,160,324
24
Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132
66,205,276
66,205,276
25
Deferred Electric Storm Restoration Costs
26
Grid Modernization Rider Under-Recovery MPSC Docket No. 2017-UN-198
2,087,335
2,087,335
27
MISO Rider Under-Recovery MPSC Docket No. 2014-UN-132
7,743,585
7,743,585
44
TOTAL
514,679,808
131,577,003
254,253,355
392,003,456


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
Non-Expense Accrued Labor
2,445,897
204,735
2,650,632
2
Section 263A
94,209
94,209
3
Mark-to-Market
11,919
11,919
4
Other
119,910
80,306
39,604
47
Miscellaneous Work in Progress
48
Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49
TOTAL
2,671,935
2,690,236


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
(a)
See Footnote
570,309,487
53,598,274
7
Other
8
TOTAL Electric (Enter Total of lines 2 thru 7)
570,309,487
53,598,274
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
570,309,487
53,598,274
Notes


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax
BALANCE AT BEG OF YEAR BALANCE AT END OF YEAR
Abandonment Loss $1,425,679  $1,425,680 
Intrst/Tax Tax Deficiencies 324,350  424,150 
Taxable Unbilled Revenue 5,825,593  6,193,525 
Property Insurance Reserve 8,394,339  7,733,496 
Capitalized Repairs 233,263  140,094 
Injuries & Damages Reserve 948,269  1,086,835 
Contribution in Aid of Construction 10,957,425  15,459,815 
Pension Plan (22,889,667) (24,857,456)
Defined Benefit Pension 34,978,624  23,955,638 
Supplemental Pension Plan 633,459  515,447 
Other Post Employment Benefits (9,831,174) (10,645,600)
Deferred Fuel (1,601,816) (20,616,355)
Removal Cost (27,702,686) (34,139,704)
Accrual of Reserves 19,222  1,303 
Asset Retirement Obligation 1,006  1,006 
Accrued Medical Claims 635,336  581,416 
Uncollectible Accounts 616,643  826,278 
Def Gain/Basis Step-Up 193,621  174,266 
Basis Step-Up 2,916,744  2,658,853 
Regulatory Liability (2,339,063) — 
Partnership Income/Loss 2,835  (35,428)
Contract Deferred Revenue 35,506  27,900 
Lease - Rental Expense 127,684  165,353 
Environmental Reserve 15,968  998 
Incentive Compensation 2,040,822  2,292,396 
Long-Term Incentive Compensation 92,750  114,512 
Stock Options 37,157  51,231 
Restricted Stock Awards 145,767  161,583 
Deferred Compensation —  1,029,188 
Income Tax Adjustment 60,433,369  58,031,426 
Tax Attribute - NOL/CR Carryforward 2,509,371  2,662,843 
ADIT-NOL-SRLY Fed NonCur 400,724,730  — 
ADIT-Tax CR Carryforward 10,100,568  13,115,670 
Fed Offset-St Carryover (22,814,841) (2,866,871)
ADIT NOL Carryforward 106,991,580  7,928,786 
ADIT-Ben-Potnt Disall UTPs Res 6,127,054  — 
TOTAL $570,309,487  $53,598,274 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
3
4
5
Total
6
Preferred Stock (Account 204)
7
8
9
10
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5
Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-04-15
Year/Period of Report

End of:
2023
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
329,266,361
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
16
MiscellaneousPaidInCapital
Ending Balance Amount
329,266,361
17
OtherPaidInCapitalAbstract
Historical Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
329,266,361


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
3.1% Series
250,000,000
1,992,167
985,000
12/11/2012
07/01/2023
12/11/2012
07/01/2023
3,853,472
3
3.75% Series
100,000,000
954,738
30,000
03/21/2014
07/01/2024
03/21/2014
07/01/2024
100,000,000
3,750,000
4
2.85% Series
375,000,000
2,878,733
120,000
05/13/2016
06/01/2028
05/13/2016
06/01/2028
375,000,000
10,687,500
5
4.9% Series
260,000,000
8,107,303
09/15/2016
10/01/2066
09/15/2016
10/01/2066
260,000,000
12,740,000
6
3.25% Series
150,000,000
1,362,173
511,500
11/14/2017
12/01/2027
11/14/2017
12/01/2027
150,000,000
4,875,000
7
4.52% Series
55,000,000
511,787
12/12/2018
12/01/2038
12/12/2018
12/01/2038
55,000,000
2,486,000
8
3.85% Series 1
300,000,000
3,171,620
3,891,000
06/05/2019
06/01/2049
06/05/2019
06/01/2049
300,000,000
11,550,000
9
3.85% Series 2
135,000,000
1,395,028
10,813,500
11/19/2019
06/01/2049
11/19/2019
06/01/2049
135,000,000
5,197,500
10
3.5% Series 1
170,000,000
2,166,734
2,410,600
05/22/2020
06/01/2051
05/22/2020
06/01/2051
170,000,000
5,950,000
11
3.5% Series 2
200,000,000
2,150,279
2,754,000
03/12/2021
06/01/2051
03/12/2021
06/01/2051
200,000,000
7,000,000
12
2.55% Series
200,000,000
1,783,526
516,000
11/16/2021
12/01/2033
11/16/2021
12/01/2033
200,000,000
5,100,000
13
5.0% Series
300,000,000
2,754,385
171,000
05/12/2023
09/01/2033
05/12/2023
09/01/2033
300,000,000
9,541,667
14
Subtotal
2,495,000,000
29,228,473
13,567,500
8,635,100
2,245,000,000
82,731,139
15
Reacquired Bonds (Account 222)
16
17
18
19
Subtotal
20
Advances from Associated Companies (Account 223)
21
22
23
24
Subtotal
25
Other Long Term Debt (Account 224)
26
Term Loan
150,000,000
162,619
06/29/2022
12/29/2023
06/29/2022
12/29/2023
7,171,389
27
Revolving Credit Facility
1,471,788
28
Subtotal
150,000,000
162,619
8,643,177
33 TOTAL
2,645,000,000
2,245,000,000
(c)
91,374,316


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: Bonds
Mortgage Bond 3.1% series was redeemed on June 30, 2023. The unamortized debt expense of $523 and unamortized debt discount of $259 has been moved to the account 189, Unamortized Loss on Reacquired Debt, and was amortized over the remaining life ending July 1, 2023.
(b) Concept: OtherLongTermDebt
Term Loan was partially repaid in the amount of $50,000,000 on May 31, 2023. The unamortized debt expense of $25,388 has been moved to the account 189, Unamortized Loss on Reacquired Debt, and will be amortized over the life of the new debt issuance ending September 1, 2033. The remaining $100,000,000 Term Loan matured December 29, 2023.
(c) Concept: InterestExpenseOnLongTermDebtIssued
Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
193,256,754
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
(a)
See Footnote Detail
21,780,568
9
Deductions Recorded on Books Not Deducted for Return
10
(b)
See Footnote Detail
6,102,492
14
Income Recorded on Books Not Included in Return
15
(c)
See Footnote Detail
296,838
19
Deductions on Return Not Charged Against Book Income
20
(d)
See Footnote Detail
144,690,965
21
(e)
Other Reconciling Items - See footnote detail
76,628,937
27
Federal Tax Net Income
476,926
28
Show Computation of Tax:
29
Normal and Surtax @ 21%
100,154
30
(f)
Estimated Consolidated Income Tax Allocated - See Footnote Detail


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription
Taxable Income Not Recorded on Books:
Avoided Cost - Tax Interest $2,369,952 
Contributions in Aid of Construction 17,843,887 
Deferred Contract Revenue 92,049 
Unbilled Revenue 1,474,680 
Total $21,780,568 
(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription
Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves ($2,225,117)
Deferred Compensation and Benefits 6,145,801 
Contingencies 400,000 
Meals and Entertainment 188,521 
Penalties 52,152 
Political Expenses 700,913 
Reserve for Uncollectible Accounts 840,222 
Total $6,102,492 
(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription
Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction $4,792,550 
Equity Earnings in Subs (4,613,521)
Tax Equity Partnership 117,809 
Total $296,838 
(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets $3,938,683 
Bond Reacquisition Loss (890,938)
Deferred Compensation & Benefits (249,608)
Deferred Fuel (64,912,808)
Depletion 379 
Depreciation of Plant Assets 190,894,458 
Service Company Billings 1,684,199 
Grand Gulf 1 Costs (20,164,570)
Pension and OPEB (6,888,902)
Prepaid Expenses 1,224,342 
Research and Development Costs (2,738,206)
Software Costs 994,167 
UOP Repairs 41,799,769 
Total $144,690,965 
(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Reconciling Items for the Year:
Net Operating Loss ($131,018,151)
Federal Income Tax Accrual - Current year (100,154)
Federal Income Tax Accrual - Prior year 20,428,399 
Investment Tax Credit (795,902)
FIN 48 taxes (150,825,754)
Provision for Deferred Income Tax 181,515,026 
State Income Tax - Current Year 25,101 
State Income Tax Accrual - Prior Year 4,142,498 
Total ($76,628,937)
(f) Concept: ComputationOfTaxDescription
The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2023. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:
FOOTNOTE DATA
Entergy Utility Property, Inc. $58,000 
Entergy Utility Affiliates, LLC (14,000)
Entergy Utility Assets Holdings, Inc. 2,575,000 
Entergy Utility Enterprises, Inc. (5,000)
Entergy Utility Group, Inc. (429,000)
System Energy Resources, Inc. (1,941,000)
Entergy Operations, Inc. (51,000)
Entergy Corporation (68,794,000)
Entergy Nuclear New York Investment Company, LLC 10,000 
Entergy Nuclear Holding Company #3, LLC (4,060,000)
Entergy Assets Management Company, LLC (3,701,000)
Entergy Northeast Holdings, LLC (12,463,000)
Entergy Power Marketing Holding II, Inc. (102,000)
Entergy Nuclear Power Marketing, LLC 1,666,000 
Entergy Nuclear, Inc. (274,000)
Entergy Nuclear Holding Company #1 (4,941,000)
Entergy Nuclear Operations, Inc. (15,892,000)
Entergy Power Holdings, Inc. 8,740,000 
Entergy TransCo HoldCo, LLC (7,000)
EAM Nelson Holding, LLC 307,000 
Entergy Power Investment Holding, Inc. 9,746,000 
Entergy Mississippi Turbine Company (380,000)
Entergy Power, LLC (227,000)
Entergy Enterprises, Inc. (33,000)
Entergy Power Gas Operations, LLC 23,740,000 
Entergy Power Marketing Holding I, Inc. (6,820,000)
Entergy Power Operations U.S., Inc. 121,000 
Entergy Nuclear Palisades, LLC (9,610,000)
Entergy Utility Affiliates Holdings, Inc. 1,000 
EWO Marketing, LLC (603,000)
Entergy Global, LLC 424,000 
Entergy Utility Assets, LLC 3,000 
Entergy Ventures, Inc. (153,000)
EUP Holdings, LLC 442,000 
Entergy Assets Management Holding, Inc. (18,000)
Entergy Technology Company (7,000)
Entergy TransCo Texas, LLC (11,000)
Entergy Services Holding, Inc. (5,005,000)
Entergy Asset Management, Inc. 4,739,000 
EWO Wind II, LLC (19,000)
Entergy Nuclear Indian Point 2, LLC (12,604,000)
Entergy Nuclear Indian Point 3, LLC (11,921,000)
Entergy Finance Company, LLC 148,108,000 
Entergy New Orleans, LLC (250,000)
Entergy Utility Holding Company, LLC (40,345,000)
Total $— 
FOOTNOTE DATA

Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC ($60,785,000)
Entergy Arkansas, LLC (4,702,000.00)
Entergy Mississippi, LLC (246,000.00)
Entergy Utility Holding Company, LLC 25,388,000.00 
Total ($40,345,000)
Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc. ($5,409,000)
Entergy Services, LLC 2,481,000.00 
Entergy Account Services, LLC (2,077,000.00)
Total ($5,005,000)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Federal Income Tax
Federal Tax
160,659,666
0
130,030,054
56,480,000
25,850,388
128,724,559
1,305,495
2
FICA
Federal Tax
857,478
0
7,001,336
7,027,720
831,094
3,158,903
3,842,433
3
Federal Uemployment Tax
Federal Tax
7,587
0
36,188
36,869
8,268
16,312
19,876
4
Federal Excise Tax
Federal Tax
0
0
28,118
28,118
0
36,761
8,643
5
Subtotal Federal Tax
161,509,557
0
122,964,412
63,572,707
0
25,027,562
0
125,512,583
0
0
2,548,171
6
State Income Tax
State Tax
3,797,799
0
4,022,543
5,611,220
5,835,964
4,349,734
327,191
7
0
0
0
0
8
Subtotal State Tax
3,797,799
0
4,022,543
5,611,220
0
5,835,964
0
4,349,734
0
0
327,191
9
Franchise - City
Local Tax
4,737,139
0
21,321,132
20,502,406
5,555,865
20,077,615
1,243,517
10
Subtotal Local Tax
4,737,139
0
21,321,132
20,502,406
0
5,555,865
0
20,077,615
0
0
1,243,517
11
Privilege License
Other Taxes
0
63,130
79,533
79,026
0
62,623
79,533
0
12
Regulatory Commission
Other Taxes
0
0
2,589,559
2,589,559
0
2,589,559
0
13
Subtotal Other Tax
0
63,130
2,669,092
2,668,585
0
0
62,623
2,669,092
0
0
0
14
Subtotal Property Tax
0
0
0
0
0
0
0
0
0
0
0
15
Subtotal Real Estate Tax
0
0
0
0
0
0
0
0
0
0
0
16
State Unemployment Tax
Unemployment Tax
92,420
0
35,218
35,967
91,671
15,450
19,768
17
Subtotal Unemployment Tax
92,420
0
35,218
35,967
0
91,671
0
15,450
0
0
19,768
18
State Use Tax
Sales And Use Tax
1,038,315
0
8,465,836
8,688,664
815,487
8,465,836
19
Subtotal Sales And Use Tax
1,038,315
0
8,465,836
8,688,664
0
815,487
0
0
0
0
8,465,836
20
Entergy Services, LLC
Income Tax
0
0
0
652,501
652,501
21
Subtotal Income Tax
0
0
0
0
0
0
0
652,501
0
0
652,501
22
State Excise Tax
Excise Tax
0
0
4,369
4,369
0
4,369
0
23
Subtotal Excise Tax
0
0
4,369
4,369
0
0
0
4,369
0
0
0
24
Subtotal Fuel Tax
0
0
0
0
0
0
0
0
0
0
0
25
Subtotal Federal Insurance Tax
0
0
0
0
0
0
0
0
0
0
0
26
Corporate Franchise Tax-MS
Franchise Tax
44,237
0
4,929,349
4,973,588
2
4,560,849
368,500
27
Corporate Franchise Tax-AR
Franchise Tax
2
19
1
18
150
150
28
Subtotal Franchise Tax
44,239
19
4,929,349
4,973,588
0
1
18
4,560,999
0
0
368,350
29
Non Income Tax
Miscellaneous Other Tax
1,300,000
0
400,000
1,700,000
400,000
0
30
Subtotal Miscellaneous Other Tax
1,300,000
0
400,000
0
0
1,700,000
0
400,000
0
0
0
31
Subtotal Other Federal Tax
0
0
0
0
0
0
0
0
0
0
0
32
Receipts & Sales
Other State Tax
2,100
0
39,964
35,419
6,645
39,964
0
33
Subtotal Other State Tax
2,100
0
39,964
35,419
0
6,645
0
39,964
0
0
0
34
Subtotal Other Property Tax
0
0
0
0
0
0
0
0
0
0
0
35
Subtotal Other Use Tax
0
0
0
0
0
0
0
0
0
0
0
36
Ad Valorem Tax - MS
Other Ad Valorem Tax
113,505,164
0
122,562,190
112,405,247
123,662,107
109,846,848
12,715,342
37
Ad Valorem Tax - AR
Other Ad Valorem Tax
1,241,951
0
1,289,888
1,262,747
1,269,092
1,289,888
0
38
Subtotal Other Advalorem Tax
114,747,115
0
123,852,078
113,667,994
0
124,931,199
0
111,136,736
0
0
12,715,342
39
Subtotal Other License And Fees Tax
0
0
0
0
0
0
0
0
0
0
0
40
Subtotal Payroll Tax
0
0
0
0
0
0
0
0
0
0
0
41
Subtotal Advalorem Tax
0
0
0
0
0
0
0
0
0
0
0
42
Entergy Services, LLC
Other Allocated Tax
0
0
0
3,516,230
3,516,230
43
Subtotal Other Allocated Tax
0
0
0
0
0
0
0
3,516,230
0
0
3,516,230
44
Subtotal Severance Tax
0
0
0
0
0
0
0
0
0
0
0
45
Subtotal Penalty Tax
0
0
0
0
0
0
0
0
0
0
0
46
Subtotal Other Taxes And Fees
0
0
0
0
0
0
0
0
0
0
0
40
TOTAL
279,673,086
63,149
42,775,169
208,538,479
0
113,909,268
62,641
21,910,107
0
0
20,865,062


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
4
7%
5
10%
4,789,512
223,476
4,566,036
(a)
20.5 years
8
TOTAL Electric (Enter Total of lines 2 thru 7)
4,789,512
223,476
4,566,036
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
Mississippi ITC
9,801,954
1,094,796
173,511
1,478,767
9,244,472
reversal of expired Ms ITC credit deferral
11
`
47 OTHER TOTAL
9,801,954
1,094,796
173,511
1,478,767
9,244,472
48 GRAND TOTAL
14,591,466
1,094,796
396,987
1,478,767
13,810,508


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome
Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
Long-Term Incentive Plan
371,744
166,614
253,833
458,963
2
Non-Qualified Pension funded status
3,615,496
1,416,559
695,363
2,894,300
3
Qualified Pension funded status
55,257,806
41,329,857
1,754,124
15,682,073
4
Liberty Development
285,000
285,000
5
Electric Line Justificantion Extension
233,900
233,900
47
TOTAL
59,763,946
42,913,030
2,703,320
19,554,236


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report


End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
716,929,779
164,615,682
88,411,036
182.3/254
7,194,790
800,329,215
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
716,929,779
164,615,682
88,411,036
7,194,790
800,329,215
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
716,929,779
164,615,682
88,411,036
7,194,790
800,329,215
10
Classification of TOTAL
11
Federal Income Tax
586,989,341
133,001,501
75,308,226
7,068,413
651,751,029
12
State Income Tax
129,940,438
31,614,181
13,102,810
126,377
148,578,186
13
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
(a)
See Footnote Detail
475,541,749
25,068,747
421,835,474
11,022,986
1,122,198
68,874,234
9 TOTAL Electric (Total of lines 3 thru 8)
475,541,749
25,068,747
421,835,474
11,022,986
1,122,198
68,874,234
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
475,541,749
25,068,747
421,835,474
11,022,986
1,122,198
68,874,234
20
Classification of TOTAL
21
Federal Income Tax
380,443,166
23,521,399
340,775,757
190
8,813,971
182.3/254
1,071,696
55,446,533
22
State Income Tax
95,098,583
1,547,348
81,059,717
190
2,209,015
182.3/254
50,502
13,427,701
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther
CHANGES DURING YEAR
BALANCE AT
BEGINNING
OF YEAR
AMOUNTS
DEBITED
TO ACCT.
410.1
AMOUNTS
CREDITED
TO ACCT.
411.1
AMOUNTS
DEBITED
TO ACCT.
410.2
AMOUNTS
CREDITED
TO ACCT.
411.2
Deferred Fuel $35,731,088  $1,827,366  $37,037,653  $—  $— 
Reg Asset Covid 19 2,457,384  493,374  493,374  —  — 
Reg Asset-Securitization 29,078,315  3,344,832  2,362,130  —  — 
Prepaid Expenses 5,346,754  4,344,889  9,070,476  —  — 
Minimum Pension Liability 34,978,599  —  —  —  — 
Bond Reacquisition Loss 2,711,242  9,355  231,644  —  — 
Section 475 Adj 357,323,315  15,037,655  372,360,970  —  — 
Capitalized Costs 1,535,746  11,276  279,227  —  — 
Income Tax Adjustment 6,379,306  —  —  —  — 
TOTAL $475,541,749  $25,068,747  $421,835,474  $—  $— 
ADJUSTMENTS
DEBITS CREDITS
ACCOUNT CREDITED AMOUNT ACCOUNT DEBITED AMOUNT BALANCE AT END OF YEAR
Deferred Fuel $—  $—  $520,801 
Reg Asset Covid 19 —  —  2,457,384 
Reg Asset-Securitization —  —  30,061,017 
Prepaid Expenses —  —  621,167 
Minimum Pension Liability 190  11,022,986  —  23,955,613 
Bond Reacquisition Loss —  —  2,488,953 
Section 475 Adj —  —  — 
Capitalized Costs —  —  1,267,795 
Income Tax Adjustment —  182.3/254 1,122,198  7,501,504 
TOTAL $11,022,986  $1,122,198  $68,874,234 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
Income Taxes
227,626,440
8,846,067
218,780,373
2
Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205
2,246,105
2,246,105
3
MISO Financial Transmission Rights Mark-to-Market
229,578
570,229
799,807
4
Electric Deferred Fuel Over-Recovery
130,645,129
130,645,129
5
MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132
1,138,340
1,138,340
6
Power Management Rider Over-Recovery MPSC Docket No. 2014-UN-132
51,116,396
51,116,396
7
Formula Rate Plan Lookback True Up MPSC Docket No. 2022-UN-137 - Amort 12 months effective 7/23
706,270
1,289,182
582,912
8
Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198
3,730,574
3,730,574
9
Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620
1,793,164
1,793,164
10
Other Post Retirement Plans
870,000
8,366,396
7,496,396
41 TOTAL
286,087,433
68,653,752
142,664,100
360,097,781


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
748,427,734
651,455,098
5,493,694
5,608,027
384,283
383,643
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
(a)
604,342,791
(d)
508,995,814
4,637,290
4,575,185
66,572
66,822
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
217,916,351
182,270,134
2,347,363
2,352,058
4,038
4,021
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
19,312,518
17,343,984
74,483
74,556
428
426
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
41,164,851
35,517,385
332,402
338,580
4,761
4,761
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
1,631,164,245
1,395,582,415
12,885,232
12,948,406
460,082
459,673
11
SalesForResaleAbstract
(447) Sales for Resale
98,254,907
165,984,871
4,416,997
2,913,988
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
1,729,419,152
1,561,567,286
17,302,229
15,862,394
460,082
459,673
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
1,729,419,152
1,561,567,286
17,302,229
15,862,394
460,082
459,673
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
7,223,291
6,732,561
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(b)
1,930,079
(e)
1,483,539
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
11,979,476
11,270,862
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(c)
1,396,513
(f)
16,745,617
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
44,778,142
51,889,728
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
92,609
6,177,413
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
67,400,110
60,808,486
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
1,796,819,262
1,622,375,772
Line12, column (b) includes $
of unbilled revenues.
Line12, column (d) includes
MWH relating to unbilled revenues


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(b) Concept: MiscellaneousServiceRevenues
Revenues from return charges and connection fee.
(c) Concept: OtherElectricRevenue
Other Electric Revenues include:
MISO Mkt Sch 11 Wholesale Dist $1,089,318 
Utility-Owned Distribution Generation Revenue 1,041,220 
Ouachita Transmission Upgrade Reimbursement 970,860 
Deposit Alternative Program 167,819 
Solar Service Fees 90,440 
Vehicle Charging Station Sales 25,177 
Annual Schedule 50 Billing 18,800 
Power Plant Reimbursement (Capital Project Excess) 6,147 
Retail Bill Credits - System Energy Settlement 1,280 
MS Department of Revenue Vendor Discount 1,150 
Third Party Sales of Inventory (7,534)
Unbilled Revenue - Includes (31,187) MWh (2,008,164)
Total $1,396,513 
(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(e) Concept: MiscellaneousServiceRevenues
Revenues from return charges and connection fee.
(f) Concept: OtherElectricRevenue
Other Electric Revenues include:

Retail bill credits - System Energy settlement ($36,667,440)
Unbilled Revenue - Includes 92,709 MWh 17,439,475 
MISO Mkt Sch 11 Wholesale Dist 1,051,487 
Ouachita Transmission Upgrade Reimbursement 970,860 
Utility-owned Distributed Generation revenue 421,521 
Solar Service Fees 23,611 
Deposit Alternative Plan 13,669 
MS Department of Revenue vendor discount 1,200 
Total ($16,745,617)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
MISO Sch 1 Sched/Sys Ctrl/Disp
155,109
304,177
483,777
626,434
2
MISO Sch 2 Reactive
95
533,809
533,821
533,825
46
TOTAL
155,204
229,632
50,044
92,609


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
RS-39C Residential Service
4,028,896
549,122,542
294,304
13,690
0.1363
2
RS-39W Residential Water Heating Service
1,432,135
188,450,420
88,930
16,104
0.1316
3
PAL-17 Private Area Lighting
28,434
8,802,692
832
34,175
0.3096
4
UFL-16 Urban Flood Lighting
6
1,188
1
6,000
0.1980
5
RFL-16 Rural Flood Lighting
2
404
1
2,000
0.2020
6
DSL-16 Directional Security  Lighting
1,449
461,687
65
22,292
0.3186
7
LED-2 LED Street and Area  Lighting
2,772
1,632,274
150
18,480
0.5888
8
GS-299 General Lighting and Power
43,473
9
IPS-26 Irrigation Pumping Power
41 TOTAL Billed Residential Sales
5,493,694
(a)
748,427,734
384,283
14,296
0.1362
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
5,493,694
748,427,734
384,283
14,296
0.1362


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled
Residential
Includes fuel adjustment revenues of:
RS-39C Residential Service $7,364,245 
RS-39W Residential Water Heating Service 2,656,556 
PAL-17 Private Area Lighting 63,518 
UFL-16 Urban Flood Lighting 14 
RFL-16 Rural Flood Lighting
DSL-16 Directional Security Lighting 3,257 
GS-299 General Lighting and Power (10)
HL-21 Public Highway & Park Lighting — 
LED-2 LED Street and Area Lighting 6,200 
TOTAL RESIDENTIAL FUEL ADJUSTMENT REVENUES $10,093,784 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 General Lighting and Power
2,432,351
365,934,992
64,119
37,935
0.1504
2
HLF-7 High Load Factor
1,187,950
120,480,438
323
3,677,864
0.1014
3
PAL-17 Private Area Lighting
13,114
4,380,618
844
15,538
0.3340
4
UFL-16 Urban Flood Lighting
183
35,441
11
16,636
0.1937
5
RFL-16 Rural Flood Lighting
7
1,652
0.2360
6
DSL-16 Directional Security  Lighting
29,574
7,324,195
593
49,872
0.2477
7
LED-2 LED Street and Area  Lighting
18,777
6,855,739
252
74,512
0.3651
8
B-34 Intermediate General Service
369,230
44,758,063
297
1,243,199
0.1212
9
SL-37 Municipal Street Lighting
26,597
4
10
TF-23 Traffic Control Signals
11
FAYETTE
466
22,775
1
466,000
0.0489
12
IPS-26 Irrigation Pumping Power
13
GS-299 MS Gen. Lghtg & Pwr Muni. Service
14
QF-18
15
Miscellaneous
7,996
89
16
ALGS-10 Alternate Large General Service
424,302
37,732,825
7
60,614,571
0.0889
17
MP-22 Municipal Pumping Power Service
18
GLP-17 Gen. Lghtg. & Pwr Redist. & Res.
1,552
211,764
1
1,552,000
0.1364
19
C-29 Large General Service
159,427
16,520,559
13
12,263,615
0.1036
20
SWH-20 Gen. Space and Water Heating Serv.
355
48,927
16
22,188
0.1378
21
RS-39C Residential Service
2
210
2
1,000
0.1050
22
RS-39W Residential Water Heating Service
41 TOTAL Billed Small or Commercial
4,637,290
(a)
604,342,791
66,572
69,658
0.1303
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43 TOTAL Small or Commercial
4,637,290
(b)
604,342,791
66,572
69,658
0.1303


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled
Commercial
Includes Fuel Adjustment Revenues of:
GS-299 General Lighting and Power $4,935,364 
B-34 Intermediate General Service 601,207 
C-29 Large General Service 495,142 
ALGS-10 Alternate Large General Service 898,119 
HLF-7 High Load Factor General Service 2,260,263 
FAYETTE — 
GLP-17 Gen. Lghtg. & Pwr for Redist. & Res. 3,123 
DSL-16 Directional Security Lighting 65,943 
SWH-20 Gen. Space and Water Heating Serv. 782 
PAL-17 Private Area Lighting $28,429 
UFL-16 Urban Flood Lighting 358 
RFL-16 Rural Flood Lighting 16 
RS-39C Residential Service (34)
RS-39W Residential Water Heating Service — 
TF-23 Traffic Control Signal — 
MP-22 Municipal Pumping Power — 
IPS-26 Irrigation Pumping Power — 
HL-21 Public Highway & Park Lighting — 
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting 39,482 
SE-29 State Institutions Service — 
GS-299 MS Gen L&P Muni Service — 
GS-298X Gen L&P TOU — 
TOTAL COMMERCIAL FUEL ADJUSTMENT REVENUES $9,328,194 
(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 General Lighting and Power
131,751
19,780,797
2,120
62,147
0.1501
2
HLF-7 High Load Factor
558,359
56,505,016
87
6,417,920
0.1012
3
PAL-17 Private Area Lighting
511
155,872
21
24,333
0.3050
4
UFL-16 Urban Flood Lighting
7
1,571
0.2244
5
RFL-16 Rural Flood Lighting
2
404
0.2020
6
DSL-16 Directional Security  Lighting
1,992
468,690
20
99,600
0.2353
7
LED-2 LED Street and Area  Lighting
701
230,079
4
175,250
0.3282
8
B-34 Intermediate General Service
134,496
18,474,104
87
1,545,931
0.1374
9
C-29 Large General Service
227,330
24,558,105
29
7,838,966
0.1080
10
IPS-26 Irrigation Pumping Power
20,071
4,449,221
1,564
12,833
0.2217
11
IP-33 Ice Manufacturing Plant Power
265
35,406
1
265,000
0.1336
12
ALGS-10 / Other
715,094
64,290,436
17
42,064,353
0.0899
13
Contract Rates
553,492
28,516,131
5
110,698,400
0.0515
14
GS-298X
3,292
450,519
83
39,663
0.1369
15
GS-299 MS Gen. Lghtg & Pwr Muni. Service
0
16
RS-39C Residential Service
0
41 TOTAL Billed Large (or Ind.) Sales
2,347,363
(a)
217,916,351
4,038
581,318
0.0928
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43 TOTAL Large (or Ind.)
2,347,363
217,916,351
4,038
581,318
0.0928


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled
Industrial
Includes Fuel Adjustment Revenues of:
GS-299 General Lighting and Power $228,971 
B-34 Intermediate General Service 168,736 
C-29 Large General Service 493,381 
ALGS-10 / Other 1,423,530 
HLF-7 High Load Factor General Service 1,233,010 
DSL-16 Directional Security Lighting 4,424 
IPS-26 Irrigation Pumping Power 30,256 
IP-33 Ice Manufacturing Plant Power 647 
PAL-17 Private Area Lighting Service 1,120 
UFL-16 Urban Flood Lighting Service 16 
RFL-16 Rural Flood Lighting Service
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting 1,478 
GS-299 MS Gen L&P Muni Service — 
GS-298X Gen L&P TOU (1,924)
CONTRACT RATES 9,756,373 
TOTAL INDUSTRIAL FUEL ADJUSTMENT REVENUES $13,340,022 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
SL-37 Municipal Street Lighting
58,194
17,019,470
138
421,696
0.2925
2
HL-21 Public Highway & Park Lighting
12,184
1,583,787
86
141,674
0.1300
3
TF-23 Traffic Control Signals
4,027
668,811
195
20,651
0.1661
4
LED-2 LED Street and Area  Lighting
78
40,450
9
8,667
0.5186
41 TOTAL Billed Public Street and Highway Lighting
74,483
(a)
19,312,518
428
174,026
0.2593
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
74,483
19,312,518
428
174,026
0.2593


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled
Public Street and Highway Lighting
Includes Fuel Adjustment Revenues of:
TF-23 Traffic Control Signals 8,857 
HL-21 Public Highway & Park Lighting 27,370 
SL-37 Municipal Street Lighting 125,560 
DSL-16 Directional Security Lighting — 
PAL-17 Private Area Lighting Service — 
LED-2 LED Street and Area Lighting 175 
TOTAL PUBLIC STREET AND HIGHWAY LIGHTING FUEL ADJUSTMENT REVENUES $161,962 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 MS Gen. Lghtg & Pwr Muni. Service
176,098
22,011,505
2,715
64,861
0.1250
2
MP-22 Municipal Pumping Power Service
83,342
11,224,074
1,947
42,805
0.1347
3
SE-29 State Institutions
69,840
7,078,042
8
8,730,000
0.1013
4
GS-299 General Lighting and Power
5
SL-37 Municipal Street Lighting
496
6
PAL-17 Private Area Lighting
410
129,133
20
20,500
0.3150
7
DSL-16 Directional Security  Lighting
2,091
507,844
62
33,726
0.2429
8
LED-2 LED Street and Area  Lighting
616
212,951
9
68,444
0.3457
9
UFL-16 Urban Flood Lighting
5
806
0.1612
41 TOTAL Billed Other Sales to Public Authorities
332,402
(a)
41,164,851
4,761
69,818
0.1238
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
332,402
41,164,851
4,761
69,818
0.1238


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled
Other Sales to Public Authorities
Includes Fuel Adjustment Revenues of:
GS-299 MS Gen. Lghtg & Pwr Muni.Service $353,351 
MP-22 Municipal Pumping Power Service 166,898 
SE-29 State Institutions 146,456 
DSL-16 Directional Security Lighting 4,591 
PAL-17 Private Area Lighting 885 
UFL-16 Urban Flood Lighting 10 
HL-21 Public Highway & Park Ltg — 
GS-299 General Lighting and Power — 
RS-39W Residential Water Heating Service — 
LED-2 LED Street and Area Lighting 1,297 
B-34 Intermediate General Service — 
TOTAL OTHER SALES TO PUBLIC AUTH FUEL ADJ REV $673,488 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
12,885,232
1,631,164,245
460,082
28,006
0.1266
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43 TOTAL - All Accounts
12,885,232
1,631,164,245
460,082
28,006
0.1266


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

    AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
Midcontinent ISO, Inc.
4,416,997
96,996,398
(a)
1,258,509
98,254,907
15
Subtotal - RQ
16
Subtotal-Non-RQ
4,416,997
96,996,398
1,258,509
98,254,907
17 Total
4,416,997
96,996,398
1,258,509
98,254,907


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale
MISO Ancillary $15,410 
MISO Residual Load 699,778 
MISO Uplift 543,321 
Total $1,258,509 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
3,072,303
3,455,138
5
FuelSteamPowerGeneration
(501) Fuel
(a)
288,973,711
(b)
509,262,621
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
2,013,031
2,757,819
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
270,404
463,557
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
7,498,836
7,820,072
11
RentsSteamPowerGeneration
(507) Rents
85,756
143,513
12
Allowances
(509) Allowances
3,401
9,363
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
301,917,442
523,912,083
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
326,210
444,077
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
657,858
936,689
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
5,385,518
8,388,292
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
2,382,294
3,498,961
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
17,150,093
18,127,326
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
25,901,973
31,395,345
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
327,819,415
555,307,428
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
987,257
900,712
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
1,080,947
1,133,250
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
12,035,265
9,750,002
66
RentsOtherPowerGeneration
(550) Rents
134,793
133,040
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
14,238,262
11,917,004
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
73,860
25,262
70
MaintenanceOfStructures
(552) Maintenance of Structures
497,314
386,288
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
6,784,962
7,583,103
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
1,012,063
890,140
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
8,368,199
8,884,793
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
22,606,461
20,801,797
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
282,228,604
322,642,544
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
843,026
743,341
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
274,593,806
256,322,872
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
557,665,436
67,063,013
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
908,091,312
643,172,238
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
3,041,266
2,434,527
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
1,926,646
2,191,750
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
42,540
41,042
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
3,719,733
4,155,039
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
529,389
373,256
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
931
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
285,753
481,753
93
StationExpensesTransmissionExpense
(562) Station Expenses
159,474
188,668
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
889,377
877,982
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
146,459
5,848,743
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
1,486,391
775,495
98
RentsTransmissionElectricExpense
(567) Rents
634,058
686,509
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
12,861,086
18,055,695
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
3,087,936
2,913,658
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
82,486
99,294
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
6,354
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
106,084
101,512
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
3,043,818
2,684,821
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
4,024,424
4,206,079
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
92,855
54,794
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
10,437,603
10,066,512
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
23,298,689
28,122,207
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
2,829,235
2,533,399
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
2,829,235
2,533,399
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
2,829,235
2,533,399
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
12,707,333
13,676,083
135
LoadDispatching
(581) Load Dispatching
142,689
170,777
136
StationExpensesDistribution
(582) Station Expenses
219,075
237,764
137
OverheadLineExpenses
(583) Overhead Line Expenses
1,161,145
1,049,452
138
UndergroundLineExpenses
(584) Underground Line Expenses
2,286,375
2,096,055
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
297,459
193,137
140
MeterExpenses
(586) Meter Expenses
2,107,155
2,188,029
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
954,848
982,290
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
4,707,241
4,425,430
143
RentsDistributionExpense
(589) Rents
2,865,033
2,517,249
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
27,448,353
27,536,266
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
947,483
1,684,887
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
676,168
708,532
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
1,431,049
1,436,426
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
32,280,902
34,790,739
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
1,691,031
1,704,652
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
122,414
334,752
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
779,462
776,259
153
MaintenanceOfMeters
(597) Maintenance of Meters
118,784
97,563
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
1,407,551
1,598,919
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
39,454,844
43,132,729
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
66,903,197
70,668,995
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
424,338
221,798
160
MeterReadingExpenses
(902) Meter Reading Expenses
867,872
949,985
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
19,039,050
21,148,904
162
UncollectibleAccounts
(904) Uncollectible Accounts
7,305,771
6,903,130
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
97,664
81,811
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
27,734,695
29,305,628
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
292,542
698,182
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
9,284,236
6,807,096
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
296,147
1,008,047
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
1,585,012
1,458,413
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
11,457,937
9,971,738
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
3,792
1,083
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
2,305,245
764,224
176
AdvertisingExpenses
(913) Advertising Expenses
294,769
1,012,696
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
192,857
179,051
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
2,796,663
1,957,054
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
31,482,736
31,763,394
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
3,695,503
2,598,364
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
1,559,708
184
OutsideServicesEmployed
(923) Outside Services Employed
22,772,013
16,990,553
185
PropertyInsurance
(924) Property Insurance
23,636,374
17,448,846
186
InjuriesAndDamages
(925) Injuries and Damages
8,747,341
3,129,102
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
24,371,997
25,412,945
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
5,414,809
4,316,685
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
728,268
961,113
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
5,066,233
4,626,144
193
RentsAdministrativeAndGeneralExpense
(931) Rents
519,332
538,182
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
124,874,898
107,785,328
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
1,447,351
1,319,622
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
126,322,249
109,104,950
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
1,169,433,977
894,836,209


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration
Includes $56,790,402 relating to certain gas hedging activities.
(b) Concept: FuelSteamPowerGeneration
Includes ($70,877,422) relating to certain gas hedging activities.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
(a)
System Energy Resources, Inc.
3,489,486
172,085,296
23,681,542
(c)
21,957,735
217,724,573
2
(b)
Entergy Arkansas, LLC
734,512
40,843,107
4,984,800
45,827,907
3
Terra Miss Nitrogen
181
15,443
15,443
4
CF Industries Nitrogen, LLC
1,292
40,676
40,676
5
Midcontinent ISO, Inc.
978,629
545,688
32,927,948
(d)
15,486,222
17,987,414
6
Small Residential Generation
950
54,478
54,478
7
Sunflower
(e)
568,999
568,999
8
Penton Solar
(f)
20,000
20,000
9
Delta Solar
(g)
20,000
20,000
15 TOTAL
5,204,688
0
0
0
213,474,091
61,674,001
7,080,512
282,228,604


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges from the Grand Gulf Nuclear Power Plant.
(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges associated with MSS-4.
(c) Concept: OtherChargesOfPurchasedPower
Represents $21,957,735 for deferral on over/under recovery under the Grand Gulf Rider.
(d) Concept: OtherChargesOfPurchasedPower
CHARGES
MISO Ancillary $682,507 
MISO Congestion (20,457,476)
MISO Losses (1,339,229)
MISO Residual Load 898,571 
MISO Uplift 4,516,190 
MISO Administration 213,215 
Total Other Purchases from MISO ($15,486,222)
(e) Concept: OtherChargesOfPurchasedPower
Cost of power received under the contract for difference associated with Sunflower.
(f) Concept: OtherChargesOfPurchasedPower
Related to System Impact Studies for Transmission Service Requests for Network Integrated Transmission Service for solar facilities.
(g) Concept: OtherChargesOfPurchasedPower
Related to System Impact Studies for Transmission Service Requests for Network Integrated Transmission Service for solar facilities.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
MISO
Various
Various
Various
Various
44,778,142
44,778,142
35 TOTAL
0
0
0
44,778,142
44,778,142


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
Midcontinent Independent System Operator Inc
(a)
86,801
(b)
59,658
146,459
TOTAL
0
0
86,801
0
59,658
146,459


FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers
The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Mississippi incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Mississippi and billed the entity for such service.
(b) Concept: OtherChargesTransmissionOfElectricityByOthers
Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
553,614
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
343,932
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
5% surcharge on regulated billings to non-regulated affiliates
56,370
7
Directors meetings and expenses
80,035
8
Mark-to-Market
11,919
9
Section 263A research - tax services
94,209
10
Legal restrictive convenants agreement
100,000
11
Mobile device services
6,701
12
IT software/hardware applications and software service contracts
3,880,949
13
Other
51,244
46
MiscellaneousGeneralExpenses
TOTAL
5,066,233


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
25,665,402
25,665,402
2
Steam Production Plant
30,175,844
35,671
30,211,515
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
27,821,655
27,821,655
7
Transmission Plant
45,181,279
45,181,279
8
Distribution Plant
100,916,026
100,916,026
9
Regional Transmission and Market Operation
10
General Plant
(a)
26,266,698
26,266,698
11
Common Plant-Electric
12
TOTAL
230,361,502
35,671
25,665,402
256,062,575
B. Basis for Amortization Charges
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Includes $3,809,288 of service company depreciation billing allocations.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year (b) + (c)
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Other expenses incurred in connection with various filings before the FERC
216,865
216,865
Electric
216,865
2
Other expenses incurred in connection with MISO and other transmission related FERC dockets
69,663
69,663
Electric
69,663
3
MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis
2,307,467
2,307,467
Electric
2,307,467
4
MPSC Docket No. 2008-UN-381 - Power Management Rider Expense
379
379
Electric
379
5
MPSC Docket No. 2009-UN-388 - Attorney General Litigation
67,082
67,082
224,249
Electric
67,082
157,167
6
MPSC Docket No. 2018-UN-205 - EML Formula Rate Plan
93,204
93,204
Electric
93,204
7
Other expenses incurred in connection with various filings before the MPSC
1,961,950
1,961,950
Electric
1,961,950
8
MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan
487,531
487,531
Electic
487,531
9
MPSC Docket No. 2023-UN-142 - EML Formula Rate Plan
210,579
210,579
Electic
210,579
10
MPSC Docket No. 2014-UN-132 - EML Formula Rate Plan
89
89
Electic
89
46
TOTAL
5,414,809
5,414,809
224,249
5,347,727
67,082
157,167


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
B(4)
Transmission University Research
1,695
1,695
2
B(4)
Environmental Research
24,993
24,993
3
B(1)
EPRI dues
34,076
34,076
4
B(1)
EPRI (1)
81,057
81,057
5
B(1)
EPRI (2)
272,973
272,973
6
B(1)
EPRI (3)
84,800
84,800
7
B(2)
Edison Electric Institute (1)
260,533
260,533
8
B(2)
Edison Electric Institute (2)
81,651
81,651
9
B(2)
Edison Electric Institute (3)
261,209
261,209
10
B(4)
SERC (1)
277,342
277,342
11
B(4)
SERC (2)
263,698
263,698
12
B(4)
North American Transmission Forum Inc
40,657
40,657


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
10,329,605
4
SalariesAndWagesElectricOperationTransmission
Transmission
581,751
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
8,613,857
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
1,997,851
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
2,132,997
9
SalariesAndWagesElectricOperationSales
Sales
135,387
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
5,053,412
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
28,844,860
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
7,072,492
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
2,530,748
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
6,238,147
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
217,550
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
16,058,937
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
17,402,097
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
3,112,499
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
14,852,004
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
1,997,851
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
2,132,997
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
135,387
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
5,270,962
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
44,903,797
44,903,797
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
44,903,797
44,903,797
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
42,445,046
42,445,046
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
42,445,046
42,445,046
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
2,702,406
2,702,406
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
2,702,406
2,702,406
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
PRELIMINARY SURVEY & INVTG CH
7,617
7,617
80
SalariesAndWagesOtherAccountsDescription
Stores Expense Undistributed (Account 163)
2,339,530
2,339,530
81
SalariesAndWagesOtherAccountsDescription
Miscellaneous Current and Accrued Assets (Account 174)
494,341
494,341
82
SalariesAndWagesOtherAccountsDescription
Clearing Accounts (Account 184)
2,272,450
2,272,450
83
SalariesAndWagesOtherAccountsDescription
Miscellaneous Deferred Debits (Account 186)
190,452
190,452
84
SalariesAndWagesOtherAccountsDescription
Accumulated Provisions for Property Insurance (Account 2281)
7,796,403
7,796,403
85
SalariesAndWagesOtherAccountsDescription
Accumulated Miscellaneous Operating Provisions (Account 2284)
2,154
2,154
86
SalariesAndWagesOtherAccountsDescription
Civil, Political, and Related Expenses (Account 4264)
494,188
494,188
87
SalariesAndWagesOtherAccountsDescription
Other Deductions (Account 4265)
17,475
17,475
88
SalariesAndWagesOtherAccountsDescription
EMPLOYMENT TAXES (Account 40811)
53,062
53,062
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
12,663,756
12,663,756
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
102,715,005
(a)
102,715,005


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: SalariesAndWagesGeneralExpense
The following payroll charges from Entergy Services are not included in this schedule and are included in the Electric O&M schedule (pages 320-323) only:

CHARGES
Production: $5,702,620 
Transmission: $4,616,461 
Distribution: $3,619,011 
Customer Accts: $2,905,933 
Customer Service: $446,615 
Sales: $477,731 
Administrative & General: $23,050,397 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
1,880,014
9,350,248
22,715,380
32,927,948
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
38,325,405
61,832,570
76,851,788
96,996,398
4 Transmission Rights
5 Ancillary Services
6 Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL
40,205,419
71,182,818
99,567,168
129,924,346


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
626,435
2
Reactive Supply and Voltage
318,598
533,826
3
Regulation and Frequency Response
4
Energy Imbalance
5
Operating Reserve - Spinning
6
Operating Reserve - Supplement
7
Other
8
Total (Lines 1 thru 7)
318,598
(a)
92,609


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount
Entergy Mississippi is a transmission owning member of Midwest Independent Transmission System Operator (MISO) RTO. Entergy Mississippi does not purchase or sell transmission services or ancillary services directly. Instead, Entergy Mississippi receives revenues and incurs expenses from transmission services and ancillary sold by MISO. MISO distributes the revenue that it receives to the transmission owner and the transmission owner pays MISO for the related expenses incurred.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: Entergy Mississippi, LLC
1
January
2,458
27
9
1,845
613
2
February
2,525
1
20
1,903
622
3
March
2,463
20
8
1,836
627
4
Total for Quarter 1
5,584
1,862
0
0
0
0
5
April
2,145
4
15
1,654
491
6
May
2,892
15
16
2,272
620
7
June
3,642
29
16
2,823
819
8
Total for Quarter 2
6,749
1,930
0
0
0
0
9
July
3,661
28
16
2,826
835
10
August
3,866
24
16
2,991
875
11
September
3,329
7
16
2,609
720
12
Total for Quarter 3
8,426
2,430
0
0
0
0
13
October
2,664
3
17
2,060
604
14
November
2,251
29
9
1,682
569
15
December
2,445
19
9
1,863
582
16
Total for Quarter 4
5,605
1,755
0
0
0
0
17
Total
26,364
7,977
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: 0
1
January
0
2
February
0
3
March
0
4
Total for Quarter 1
0
0
0
0
0
0
5
April
0
6
May
0
7
June
0
8
Total for Quarter 2
0
0
0
0
0
0
9
July
0
10
August
0
11
September
0
12
Total for Quarter 3
0
0
0
0
0
0
13
October
0
14
November
0
15
December
0
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-04-15
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
12,885,232
3
Steam
12,794,468
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
4,416,997
5
Hydro-Conventional
25
Energy Furnished Without Charge
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
23,726
7
Other
1,204
27
Total Energy Losses
674,405
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
12,795,672
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
18,000,360
10
Purchases (other than for Energy Storage)
5,204,688
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
0
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
18,000,360


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: Entergy Mississippi, LLC
29
January
1,769,854
733,055
1,953
27
9
30
February
1,341,805
408,619
2,026
1
20
31
March
1,356,812
389,112
1,961
20
8
32
April
1,379,421
483,660
1,854
4
16
33
May
1,396,678
285,324
2,405
15
16
34
June
1,701,808
381,068
2,931
29
16
35
July
1,807,104
311,703
2,911
31
16
36
August
1,932,343
326,789
3,127
24
16
37
September
1,526,420
266,386
2,752
7
16
38
October
1,541,759
527,998
2,233
3
17
39
November
979,318
57,554
1,800
29
9
40
December
1,267,038
245,729
1,875
11
9
41
Total
18,000,360
4,416,997


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
Attala
Plant Name:
Baxter Wilson
Plant Name:
Choctaw
Plant Name:
Gerald Andrus
Plant Name:
Hinds
Plant Name:
(a)
Independence
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
Gas Turbine
Steam
Combined Cycle
Steam
Gas Turbine
Steam
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
Outdoor Boiler
Outdoor
Outdoor Boiler
Outdoor Boiler
3
YearPlantOriginallyConstructed
Year Originally Constructed
1905
1966
2019
1975
2001
1983
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
1905
1971
2019
1975
2001
1984
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
551
545
899
781
600
1,800
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
515
0
910
641
556
1,710
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
6,445
0
6,683
754
7,472
10,494
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
501
559
848
750
526
1,681
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
458
494
798
707
481
1,663
11
PlantAverageNumberOfEmployees
Average Number of Employees
26
4
30
29
35
51
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
2,943,994,961
5,144,356,323
213,040,798
3,310,273,327
1,182,803,371
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
128,931
90,432
2,761,498
331,301
1,362,657
1,068,160
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
18,533,587
385,452
208,586,182
31,587,099
101,260,727
22,332,444
15
CostOfEquipmentSteamProduction
Equipment Costs
122,329,878
294,921,721
171,504,625
236,216,410
259,816,242
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
136,135
1,507,847
17
CostOfPlant
Total cost (total 13 thru 20)
140,992,396
612,019
506,269,401
203,423,025
338,839,794
284,724,693
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
256
1
563
260
564
158
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
867,794
17,464
467,136
1,424,761
685,205
597,200
20
FuelSteamPowerGeneration
Fuel
43,871,916
114,862
93,405,014
6,105,197
55,385,584
33,306,335
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
0
22
SteamExpensesSteamPowerGeneration
Steam Expenses
16,225
14,716
27,463
1,527,851
17,035
409,741
23
SteamFromOtherSources
Steam From Other Sources
0
24
SteamTransferredCredit
Steam Transferred (Cr)
0
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
870,505
11,224
2,161
210,441
257,020
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
7,076,502
239,541
2,165,385
2,838,055
5,631,172
1,505,138
27
RentsSteamPowerGeneration
Rents
117,008
15,263
10,717
31,758
30,764
15,039
28
Allowances
Allowances
162
197
920
185
1,937
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
94,184
3
34,401
194,115
21,338
56,029
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
309,819
95
116
424,233
187,635
233,274
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
1,120
26,579
1,897
2,278,362
1,176
3,137,928
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
3,320,083
1,748
4,309
1,022,249
3,470,098
1,348,769
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
332,242
8,985
13,875,269
445,103
1,316,097
2,184,460
34
PowerProductionExpensesSteamPower
Total Production Expenses
56,875,320
397,322
109,988,110
16,294,765
66,954,378
43,052,870
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
0.0193
0.0214
0.0765
0.0202
0.0364
35
FuelKindAxis
Plant Name
Attala
Baxter Wilson
Baxter Wilson
Choctaw
Gerald Andrus
Gerald Andrus
Hinds
Independence
Independence
36
FuelKind
Fuel Kind
Gas
Gas
Oil
Gas
Gas
Oil
Gas
Coal
Oil
37
FuelUnit
Fuel Unit
Mcf
Mcf
bbl
Mcf
Mcf
bbl
Mcf
T
bbl
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
17,981,238
0
0
33,033,311
2,338,240
257
21,928,252
72,845
4,144
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
1,055,086
0
0
1,073,473
1,041,965
140,476
1,066,741
87,400
140,476
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
2
3
3
232
3
449
72
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
2
3
2
39
2
3
12
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation
6,444
6,893
11,443
7,066
24,791


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: PlantName
Indepedence - Reflects Entergy Mississippi's 25% ownership interest in Independence Units 1 and 2.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net kWh


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
25
WaterForPower
Water for Power
26
PumpedStorageExpenses
Pumped Storage Expenses
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
29
RentsPumpedStoragePlant
Rents
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Account for Project Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35 TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
ENERGY STORAGE OPERATIONS (Small Plants)
  1. Small Plants are plants less than 10,000 Kw.
  2. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project.
  4. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined.
  5. If any other expenses, report in column (i) and footnote the nature of the item(s).
BALANCE AT BEGINNING OF YEAR
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
Project Cost
(d)
Operations (Excluding Fuel used in Storage Operations)
(e)
Maintenance
(f)
Cost of fuel used in storage operations
(g)
Account No. 555.1, Power Purchased for Storage Operations
(h)
Other Expenses
(i)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36 TOTAL
0
0
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
6,749,711
5,359,237
118,598
12,227,546
2
BAXTER WILSON
GRAND GULF 500 - [5620]
500
500
21.46
0.00
1
954 ACSR
3
BAXTER WILSON
PERRYVILLE 500 - [5200]
500
500
1.46
0.00
1
3070 AACSR
4
BAXTER WILSON
RAY BRASWELL 500 - [6880]
500
500
30.14
5.40
2
954 ACSR
5
BOGALUSA 500
FRANKLIN EHV - [5521]
500
500
51.38
0.00
1
954 ACSR
6
CHOCTAW
FRENCH CAMP 500 - [5014]
500
500
0.81
0.00
1
954 ACSR
7
FRANKLIN
GRAND GULF 500 - [5640]
500
500
43.46
0.00
1
954 ACSR
8
FRANKLIN
RAY BRASWELL 500 - [6980]
500
500
58.30
0.00
1
954 ACSR
9
MCADAMS
LAKEOVER 500 - [6960]
500
500
57.44
0.00
1
954 ACSR
10
MCKNIGHT
FRANKLIN 500 - [6980]
500
500
38.36
0.00
1
[3]-954 ACSR
11
RAY BRASWELL
LAKEOVER 500 - [7130]
500
500
19.10
3.40
2
954 ACSR
12
WOLF CREEK
CHOCTAW 500 - [5015]
500
500
0.11
0.00
1
954 ACSR
13
WOLF CREEK
FRENCH CAMP 500 - [6960]
500
500
0.83
0.00
1
954 ACSR
14
WOLF CREEK
MCADAMS 500 - [6960]
500
500
24.21
0.00
1
954 ACSR
15
Total 500kV
5,483,196
63,568,368
69,051,564
16
BATESVILLE
SIX MILE LAKE 230 kV - [52301]
230
230
0.00
28.50
2
17
CATLETT
YANDELL RD 230 - [2343]
230
230
10.11
2.30
2
1272 ACSR
18
CATLETT
SOUTH CANTON 230 - [2392]
230
230
3.60
0.00
1
1272 ACSR
19
CATLETT
TINNIN RD 230 - [5112]
230
230
22.99
2.30
2
1272 ACSR
20
FREEPORT
HORN LAKE 230 - [5942]
230
230
3.81
0.00
1
954 ACSR
21
GERALD ANDRUS
LAKE VILLAGE BAGBY 230 - [5540]
230
230
3.59
0.00
1
1534.4 ACAR
22
GERALD ANDRUS
INDIANOLA 230 - [5580]
230
230
25.30
8.40
2
1272 ACSR
23
GETWELL
BYHALA 230 - [2341]
230
230
5.88
0.00
1
1272 ACSR
24
GETWELL
TWINKLETOWN 230 - [5007]
230
230
19.14
1.40
2
1272 ACSR
25
HORN LAKE
GETWELL 230 - [6186]
230
230
3.80
4.80
2
1272 ACSR
26
INDIANOLA
TILLATOBA 230 - [6020]
230
230
56.36
0.00
1
1272 ACSR
27
LAKEOVER
LUCKNEY 230 - [2311]
230
230
14.40
8.40
2
1272 ACSR
28
LAKEOVER
YANDELL RD 230 - [2335]
230
230
8.14
10.20
2
1272 ACSR
29
LAKEOVER
HINDS2 BLACKSTART GT3 - [2342]
230
230
0.70
0.00
1
954 ACSR
30
LAKEOVER
REX BROWN (EAST) 230 - [6184]
230
230
0.18
1.60
2
1272 ACSR
31
LAKEOVER
REX BROWN (WEST) 230 - [6183]
230
230
0.18
1.60
2
1272 ACSR
32
LUCKNEY
RANKIN 230 - [6298]
230
230
13.47
0.00
1
1272 ACSR
33
MCADAMS
ATTALA 230 - [6415]
230
230
1.17
0.00
1
1272 ACSR
34
MCADAMS
INDIANOLA 230 - [6410]
230
230
67.53
0.00
1
1272 ACSR
35
MCADAMS
PICKENS 230 - [6416]
230
230
16.18
0.00
1
954 ACSR
36
RAY BRASWELL
S JACKSON 230 - [7370]
230
230
0.23
9.20
2
1272 ACSR
37
RAY BRASWELL
SOUTH JACKSON 230 - [7375]
230
230
2.58
11.00
2
1272 ACSR
38
RAY BRASWELL
NORREL 230 - [2340]
230
230
4.14
3.20
2
1272 ACSR
39
RAY BRASWEL
REX BROWN 230 - [7100]
230
230
9.18
0.00
1
1272 ACSS
40
RITCHIE
MOON LAKE 230 - [6320]
230
230
6.80
0.00
1
1947.5 ACSR
41
RITCHIE
TUNICA 230 - [7490]
230
230
21.36
0.00
1
1947.5 ACSR
42
SIX MILE LAKE
MOON LAKE SS 230 kV - [52347]
230
230
0.03
4.50
2
43
SOUTH CANTON
RAGSDALE 230 LN 1 - [5271]
230
230
0.24
1.30
2
1272 ACSR
44
SOUTH CANTON
RAGSDALE 230 LN 2 - [5271]
230
230
0.26
1.30
2
1272 ACSR
45
SOUTH CANTON
YANDEL RD 230 - [52314]
230
230
6.04
3.60
2
1272 ACSR
46
SOUTH CANTON
PICKENS 230 - [5270,6185]
230
230
26.05
1.90
2
1272 ACSR
47
SOUTH JACKSON
RANKIN 230 - [7350]
230
230
2.39
15.30
2
1272 ACSR
48
TILLATOBA
BATESVILLE 230 - [5840]
230
230
27.22
0.00
1
1780 ACSR
49
TILLATOBA
SOUTH GRENADA 230 - [2337]
230
230
3.24
16.00
2
1272 ACSR
50
TINNIN RD
GERALD ANDRUS 230 - [52304,52391]
230
230
70.50
8.40
2
1272 ACSR
51
TINNIN RD
NORREL 230 - [2339]
230
230
6.91
0.00
1
1272 ACSR
52
TUNICA
TWINKLETOWN 230 - [5525]
230
230
21.09
2.50
2
1272 ACSR
53
TWINKLETOWN
FREEPORT 230 - [5525]
230
230
8.30
0.00
1
1272 ACSR
54
Total 230kV
43,122,884
221,882,897
265,005,781
55
HORN LAKE
ALLEN S 161 - [5960]
161
161
5.90
0.00
1
954 ACSS
56
Total 161kV
9,982
397,075
407,057
57
Total 115kV
1,892.30
136.30
43,262,198
676,873,697
720,135,895
36 TOTAL
2,738.35
292.80
76
91,878,260
962,722,037
1,054,600,297
6,749,711
5,359,237
118,598
12,227,546


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
TOTAL
0.00
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
AIRPORT/JACKSON
Distribution
Unattended
(a)
115.0
(b)
14.5
56.0
2
0
2
ATTALA
Distribution
Unattended
230.0
13.8
20.0
1
0
3
BELZONI
Distribution
Unattended
115.0
13.9
44.8
2
0
4
BOLTON
Distribution
Unattended
115.0
13.9
18.8
2
0
5
BOVINA
Distribution
Unattended
115.0
12.5
11.2
1
0
6
BOZEMAN ROAD
Distribution
Unattended
230.0
13.8
73.3
2
0
7
BRANDON
Distribution
Unattended
115.0
14.4
89.3
3
0
8
BRICKYARD
Distribution
Unattended
115.0
14.4
33.3
1
0
9
BROOKHAVEN
Distribution
Unattended
115.0
14.4
94.7
3
0
10
BROOKHAVEN/SOUTH
Distribution
Unattended
115.0
14.4
61.3
2
0
11
BYHALIA
Distribution
Unattended
230.0
12.5
40.0
1
0
12
BYRAM
Distribution
Unattended
115.0
14.5
66.9
2
0
13
CANTON
Distribution
Unattended
230.0
13.9
67.2
2
0
14
CANTON ROAD/JACKSON
Distribution
Unattended
115.0
14.5
66.9
2
0
15
CANTON/SOUTH
Distribution
Unattended
230.0
13.8
73.3
2
0
16
CARTHAGE (MS)
Distribution
Unattended
115.0
13.9
44.8
2
0
17
CATLETT
Distribution
Unattended
230.0
12.5
80.0
2
0
18
CENTREVILLE
Distribution
Unattended
115.0
13.9
40.0
2
0
19
CHARITY CHURCH/JACKSON
Distribution
Unattended
230.0
14.4
66.9
2
0
20
CHARLESTON
Distribution
Unattended
115.0
13.9
22.4
1
0
21
CHURCH ROAD
Distribution
Unattended
230.0
14.4
40.0
1
0
22
CLARKSDALE
Distribution
Unattended
115.0
13.8
40.0
2
0
23
CLEVELAND [MS]
Distribution
Unattended
115.0
13.9
84.0
3
0
24
CLEVELAND/SOUTH
Distribution
Unattended
115.0
13.9
56.0
2
0
25
CLINTON [MS]
Distribution
Unattended
115.0
14.5
50.4
2
0
26
CLINTON INDUSTRIAL
Distribution
Unattended
230.0
14.5
61.3
2
0
27
COLDWATER
Distribution
Unattended
115.0
13.8
66.6
2
0
28
COMO
Distribution
Unattended
115.0
13.9
20.0
2
0
29
COUNTRY CLUB/JACKSON
Distribution
Unattended
115.0
14.4
61.3
2
0
30
CRENSHAW
Distribution
Unattended
115.0
13.9
22.4
1
0
31
CRYSTAL SPRINGS
Distribution
Unattended
115.0
13.9
44.8
2
0
32
DESOTO
Distribution
Unattended
115.0
14.5
56.0
2
0
33
DREW [MS]
Distribution
Unattended
115.0
13.9
34.9
2
0
34
DURANT
Distribution
Unattended
115.0
14.5
32.5
2
0
35
EDWARDS
Distribution
Unattended
115.0
13.8
32.5
2
0
36
ELLIOTT
Distribution
Unattended
115.0
14.4
55.7
2
0
37
ELTON RD
Distribution
Unattended
115.0
13.9
20.0
1
0
38
ENID
Distribution
Unattended
230.0
14.4
20.0
1
0
39
FANNIN ROAD
Distribution
Unattended
115.0
13.9
50.4
2
0
40
FAYETTE
Distribution
Unattended
115.0
13.8
20.0
1
0
41
FERNWOOD
Distribution
Unattended
115.0
13.9
44.8
2
0
42
FLORA
Distribution
Unattended
115.0
14.5
68.0
2
0
43
FLORENCE
Distribution
Unattended
115.0
14.4
61.3
2
0
44
FLOWERS
Distribution
Unattended
115.0
13.8
40.0
2
0
45
FLOWOOD
Distribution
Unattended
115.0
14.5
66.7
2
0
46
FONDREN/JACKSON
Distribution
Unattended
115.0
14.5
78.1
3
0
47
FOREST HILL/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
48
GALLATIN STREET/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
49
GALLMAN
Distribution
Unattended
115.0
13.9
44.8
2
0
50
GEORGETOWN [MS]
Distribution
Unattended
115.0
13.8
12.5
1
0
51
GETWELL
Distribution
Unattended
230.0
13.8
80.0
2
0
52
GLEN ALLAN
Distribution
Unattended
115.0
13.9
5.0
1
0
53
GLOSTER
Distribution
Unattended
115.0
14.4
74.9
3
0
54
GRAND GULF DISTRIBUTION
Distribution
Unattended
115.0
14.5
20.0
1
0
55
GRANTS FERRY
Distribution
Unattended
230.0
13.9
70.9
2
0
56
GREENBROOK
Distribution
Unattended
115.0
14.4
94.7
3
0
57
GREENVILLE
Distribution
Unattended
115.0
13.9
56.0
2
0
58
GREENVILLE/EAST
Distribution
Unattended
115.0
13.9
42.4
2
0
59
GREENVILLE/INDUSTRIAL
Distribution
Unattended
115.0
13.9
50.4
2
0
60
GREENVILLE/MIDTOWN
Distribution
Unattended
115.0
13.9
44.8
2
0
61
GREENVILLE/NORTH
Distribution
Unattended
115.0
14.5
94.6
3
0
62
GREENVILLE/SOUTHEAST
Distribution
Unattended
115.0
13.9
28.0
1
0
63
GREENWOOD
Distribution
Unattended
115.0
13.9
44.8
2
0
64
GRENADA
Distribution
Unattended
115.0
13.9
78.4
3
0
65
GRENADA/SOUTH
Distribution
Unattended
230.0
13.9
50.4
2
0
66
HAINING ROAD
Distribution
Unattended
115.0
13.9
50.4
2
0
67
HAZLEHURST
Distribution
Unattended
115.0
13.9
50.4
2
0
68
HENDERSON ROAD
Distribution
Unattended
230.0
13.8
80.0
2
0
69
HERNANDO
Distribution
Unattended
115.0
13.9
83.2
2
0
70
HOLLANDALE
Distribution
Unattended
115.0
13.9
50.4
2
0
71
HORN LAKE
Distribution
Unattended
230.0
14.5
100.2
3
0
72
HOY ROAD
Distribution
Unattended
230.0
13.9
67.2
2
0
73
INDIANOLA 115 SUB
Distribution
Unattended
115.0
13.9
56.0
2
0
74
INVERNESS
Distribution
Unattended
115.0
13.8
40.0
2
0
75
JACKSON/EAST
Distribution
Unattended
115.0
13.9
100.5
3
0
76
JACKSON/NORTH
Distribution
Unattended
115.0
13.9
72.8
3
0
77
JACKSON/NORTHEAST
Distribution
Unattended
115.0
13.9
62.4
3
0
78
JACKSON/NORTHWEST
Distribution
Unattended
115.0
14.5
56.0
2
0
79
JACKSON/SOUTH
Distribution
Unattended
230.0
13.9
67.2
2
0
80
JACKSON/SOUTHWEST
Distribution
Unattended
115.0
13.9
44.8
2
0
81
JACKSON/TREATMENT PLANT
Distribution
Unattended
115.0
4.2
12.5
1
0
82
JACKSON/WATERWORKS
Distribution
Unattended
14.0
83
JACKSON/WEST
Distribution
Unattended
115.0
13.9
56.0
2
0
84
JOHNS MANVILLE
Distribution
Unattended
115.0
14.4
61.3
2
0
85
JONESTOWN
Distribution
Unattended
115.0
13.8
10.5
1
0
86
KINGSWOOD/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
87
KOSCIUSKO
Distribution
Unattended
115.0
14.4
68.0
2
0
88
LAKE CASTLE
Distribution
Unattended
230.0
14.5
66.7
2
0
89
LARSON ST/JACKSON
Distribution
Unattended
115.0
14.5
33.6
1
0
90
LELAND
Distribution
Unattended
115.0
14.5
45.8
2
0
91
LEXINGTON
Distribution
Unattended
115.0
13.9
42.4
2
0
92
LIBERTY
Distribution
Unattended
115.0
13.9
30.0
2
0
93
LIVINGSTON ROAD/JACKSON
Distribution
Unattended
115.0
14.4
62.4
2
0
94
LUCKNEY
Distribution
Unattended
230.0
13.9
67.2
2
0
95
LULA
Distribution
Unattended
115.0
13.9
20.0
1
0
96
MADISON
Distribution
Unattended
115.0
13.8
80.0
2
0
97
MAGEE
Distribution
Unattended
115.0
14.5
50.4
2
0
98
MARKS
Distribution
Unattended
115.0
13.9
44.8
2
0
99
MCCOMB
Distribution
Unattended
115.0
13.9
61.3
2
0
100
MCCOMB/WEST
Distribution
Unattended
115.0
13.9
50.4
2
0
101
MEADVILLE
Distribution
Unattended
115.0
13.9
20.0
1
0
102
MEDICAL CENTER/JACKSON
Distribution
Unattended
115.0
13.9
67.2
2
0
103
MENDENHALL
Distribution
Unattended
115.0
14.5
44.8
2
0
104
MIAMI STREET/JACKSON
Distribution
Unattended
115.0
14.4
33.3
1
0
105
MIDNIGHT
Distribution
Unattended
115.0
13.9
27.4
2
0
106
MILL STREET
Distribution
Unattended
115.0
13.8
80.0
2
0
107
MONUMENT STREET/JACKSON
Distribution
Unattended
115.0
14.5
76.0
3
0
108
MOORHEAD
Distribution
Unattended
115.0
14.5
48.0
2
0
109
MORTON
Distribution
Unattended
115.0
14.4
33.3
1
0
110
NATCHEZ
Distribution
Unattended
115.0
14.4
61.3
2
0
111
NATCHEZ/INDUSTRIAL PARK
Distribution
Unattended
115.0
14.5
55.7
2
0
112
NATCHEZ/SOUTH
Distribution
Unattended
115.0
13.9
50.4
2
0
113
NESBIT
Distribution
Unattended
115.0
14.4
55.7
2
0
114
NEW HEBRON
Distribution
Unattended
115.0
13.8
10.5
1
0
115
NORTHPARK
Distribution
Unattended
230.0
14.4
66.3
2
0
116
NORTHSIDE DRIVE/JACKSON
Distribution
Unattended
230.0
13.9
56.0
2
0
117
PELAHATCHIE
Distribution
Unattended
115.0
14.5
22.4
1
0
118
PICKENS
Distribution
Unattended
230.0
13.9
28.5
2
0
119
PLUM POINT
Distribution
Unattended
115.0
14.5
106.7
3
0
120
PORT GIBSON
Distribution
Unattended
115.0
13.9
68.0
2
0
121
RALEIGH
Distribution
Unattended
115.0
13.9
30.5
2
0
122
RANKIN
Distribution
Unattended
230.0
14.4
61.3
2
0
123
RANKIN INDTRL./JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
124
RAYMOND
Distribution
Unattended
115.0
14.5
56.0
2
0
125
REX BROWN 115 SWYD
Distribution
Unattended
115.0
13.8
40.0
1
0
126
RIDGELAND
Distribution
Unattended
115.0
14.5
66.6
2
0
127
ROBINSON ROAD/JACKSON
Distribution
Unattended
230.0
13.9
56.0
2
0
128
ROBINSONVILLE
Distribution
Unattended
230.0
34.5
133.3
3
0
129
ROLLING FORK
Distribution
Unattended
115.0
13.9
34.9
2
0
130
ROSEDALE [MS]
Distribution
Unattended
115.0
13.9
34.9
2
0
131
ROXIE
Distribution
Unattended
115.0
14.4
10.5
1
0
132
RULEVILLE
Distribution
Unattended
115.0
13.9
42.4
2
0
133
SARDIS
Distribution
Unattended
115.0
13.8
40.0
2
0
134
SCHLATER
Distribution
Unattended
115.0
13.9
21.9
2
0
135
SENATOBIA
Distribution
Unattended
115.0
14.4
73.3
2
0
136
SHELBY
Distribution
Unattended
115.0
13.9
20.9
2
0
137
SILVER CREEK
Distribution
Unattended
115.0
13.9
50.4
2
0
138
SNOWDEN PARK
Distribution
Unattended
115.0
13.9
80.0
2
0
139
SPENCER POTASH
Distribution
Unattended
115.0
13.9
22.4
1
0
140
SPRING RIDGE ROAD
Distribution
Unattended
115.0
13.9
33.6
1
0
141
STAR
Distribution
Unattended
115.0
13.9
22.5
2
0
142
STRINGTOWN
Distribution
Unattended
115.0
13.9
12.5
1
0
143
SUNNYBROOK
Distribution
Unattended
115.0
13.8
40.0
1
0
144
TERRY
Distribution
Unattended
115.0
13.8
51.9
2
0
145
TINNIN ROAD
Distribution
Unattended
230.0
13.8
40.0
1
0
146
TUNICA
Distribution
Unattended
115.0
13.9
22.4
1
0
147
TWINKLETOWN
Distribution
Unattended
230.0
14.4
33.3
1
0
148
TYLERTOWN
Distribution
Unattended
115.0
13.9
37.5
3
0
149
UTICA
Distribution
Unattended
115.0
13.9
30.5
2
0
150
VICKSBURG
Distribution
Unattended
115.0
13.9
42.4
2
0
151
VICKSBURG/EAST
Distribution
Unattended
115.0
13.9
42.4
2
0
152
VICKSBURG/NORTH
Distribution
Unattended
115.0
13.9
70.4
3
0
153
VICKSBURG/OPENWOOD
Distribution
Unattended
115.0
13.8
73.3
2
0
154
VICKSBURG/SOUTH
Distribution
Unattended
115.0
13.9
42.4
2
0
155
VICKSBURG/SOUTHEAST
Distribution
Unattended
115.0
13.9
28.0
1
0
156
VICKSBURG/WEST
Distribution
Unattended
115.0
14.4
53.0
2
0
157
WALLS
Distribution
Unattended
115.0
13.9
9.4
1
0
158
WEBB
Distribution
Unattended
115.0
13.9
16.9
2
0
159
WESSON
Distribution
Unattended
115.0
14.5
28.0
1
0
160
WHITFIELD
Distribution
Unattended
115.0
13.9
22.4
1
0
161
WINONA
Distribution
Unattended
115.0
13.9
55.4
2
0
162
WOODVILLE [MS]
Distribution
Unattended
115.0
13.9
12.5
1
0
163
WYNNDALE
Distribution
Unattended
115.0
13.8
80.0
2
0
164
YANDELL RD
Distribution
Unattended
230.0
13.9
100.3
3
0
165
YAZOO CITY SS
Distribution
Unattended
115.0
13.9
12.5
1
0
166
ATTALA
Transmission
Unattended
230.0
120.0
(c)
13.8
391.8
1
0
167
ATTALA PLANT
Transmission
Unattended
500.0
168
BATESVILLE [MS]
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
169
BAXTER WILSON SES SWYD
Transmission
Unattended
500.0
115.0
1176.0
2
0
170
BEECH GROVE SS
Transmission
Unattended
115.0
171
BOWLING GREEN SS
Transmission
Unattended
115.0
172
CHOCTAW
Transmission
Unattended
500.0
173
DELTA SWYD
Transmission
Unattended
115.0
174
ELLIOTT SS
Transmission
Unattended
115.0
175
FRANKLIN EHV
Transmission
Unattended
500.0
115.0
13.8
1120.0
2
0
176
FREEPORT
Transmission
Unattended
500.0
230.0
13.9
975.0
1
0
177
GERALD ANDRUS SES SWYD
Transmission
Unattended
230.0
120.0
13.9
392.0
1
0
178
GETWELL
Transmission
Unattended
230.0
115.0
13.8
392.0
1
0
179
GRAND GULF TRANSMISSION
Transmission
Unattended
500.0
180
GRENADA/SOUTH
Transmission
Unattended
230.0
115.0
500.0
1
0
181
HARPER
Transmission
Unattended
115.0
182
HORN LAKE
Transmission
Unattended
230.0
161.0
13.8
1027.0
3
0
183
INDIANOLA 230/115 SUB
Transmission
Unattended
230.0
120.0
391.8
1
0
184
JACKSON/SOUTH
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
185
JONESTOWN SS
Transmission
Unattended
115.0
186
LAKEOVER EHV
Transmission
Unattended
500.0
230.0
1215.0
2
0
187
MCADAMS EHV
Transmission
Unattended
500.0
230.0
1500.0
2
0
188
MERCHANT ROAD
Transmission
Unattended
115.0
189
MINTER CITY SS
Transmission
Unattended
115.0
190
MOON LAKE SS
Transmission
Unattended
230.0
191
NATCHEZ SWYD
Transmission
Unattended
115.0
192
NORTHPARK
Transmission
Unattended
230.0
115.0
13.8
400.0
1
0
193
PICKENS
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
194
RANKIN
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
195
RAY BRASWELL EHV
Transmission
Unattended
500.0
230.0
13.9
2073.0
4
0
196
REX BROWN 230 SWYD
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
197
SHELBY SS
Transmission
Unattended
115.0
198
SIX MILE LAKE
Transmission
Unattended
230.0
199
TILLATOBA
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
200
TUNICA 230/115 SUB
Transmission
Unattended
230.0
120.0
391.8
1
0
201
VALLEY HILL
Transmission
Unattended
115.0
202
VICKSBURG/EAST SS
Transmission
Unattended
115.0
203
WOLF CREEK
Transmission
Unattended
500.0
204
YAZOO CITY MUNICIPAL SS
Transmission
Unattended
115.0
205
TotalDistributionSubstationMember
165
206
TotalGenerationSubstationMember
0
207
TotalTransmissionSubstationMember
39
208
Total
204


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: PrimaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(b) Concept: SecondaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(c) Concept: TertiaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
(a)
See footnote for schedule details
3
(b)
See footnote for allocation method details
19
20
Non-power Goods or Services Provided for Affiliated
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/15/2024
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNonPowerGoodOrService
Non-power goods or services received from or provided to associated (affiliated) companies are reported in the schedule below by type of category, where the amount charged or credited from or to each affiliate is equal to or greater than the $250,000 threshold.                

Line No. Description of the Non-Power Good or Service Name of Associated/Affiliated Company Account Charged or Credited Amount Charged or Credited
(a) (b) (c) (d)
1 Non-power Goods or Services Provided by Affiliate
2 Support - Corporate Entergy Services, LLC 107000, 108220, 108230, 118001, 163000, 174101, 174200, 181CPD, 183000, 183KSL, 184001, 1840FS, 184EPC, 184EST, 228100, 4031AM, 408110, 408155, 408158, 426100, 426400, 426500, 430000, 431000, 454000, 500000, 506000, 507000, 510000, 512000, 513000, 514000, 546000, 549000, 551000, 556000, 557000, 560000, 561200, 561300, 561500, 563000, 566000, 568000, 573000, 580000, 581000, 583000, 584000, 585000, 586000, 587000, 588000, 589000, 590000, 592000, 593000, 594000, 595000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 904000, 905000, 907000, 908000, 909000, 910000, 912000, 916000, 920000, 921000, 922000, 923000, 924000, 925000, 926000, 926NS1, 928000, 930100, 930200, 931000, 935000 78,733,826 
3 Support - Finance and Accounting Entergy Services, LLC 107000, 163000, 174101, 181CPD, 183000, 183KSL, 184001, 1840FS, 228100, 408110, 426100, 426400, 426500, 4265OM, 506000, 514000, 560000, 580000, 586000, 588000, 901000, 902000, 903001, 903002, 905000, 908000, 912000, 913000, 920000, 921000, 922000, 923000, 924000, 925000, 925INS, 926000, 928000, 930100, 930200, 931000 17,198,729 
4 Support - Power Generation Entergy Services, LLC 107000, 108220, 163000, 183000, 183KSL, 228100, 408110, 426100, 426400, 426500, 500000, 506000, 507000, 510000, 511000, 512000, 513000, 514000, 546000, 549000, 551000, 560000, 561200, 5612BA, 566000, 580000, 589000, 920000, 921000, 922000, 923000, 926000, 928000, 930100, 930200 8,718,935 
5 Support - Information Technology Entergy Services, LLC 107000, 108220, 165C01, 174101, 174200, 184001, 228100, 408110, 426100, 426400, 426500, 454000, 500000, 506000, 513000, 514000, 549000, 560000, 566000, 568000, 569200, 573000, 580000, 588000, 598000, 903001, 910000, 920000, 921000, 922000, 923000, 926000, 930100, 930200, 931000, 935000 28,273,516 
6 Support - Power Delivery Entergy Services, LLC 107000, 108220, 108230, 163000, 174101, 174200, 183000, 183KSL, 184001, 1840FS, 184EPC, 184EST, 228100, 228400, 408110, 426100, 426400, 426500, 500000, 506000, 507000, 514000, 546000, 556000, 557000, 560000, 561200, 5612BA, 561300, 561500, 563000, 566000, 567000, 568000, 569000, 569200, 573000, 580000, 581000, 583000, 584000, 585000, 586000, 587000, 588000, 589000, 590000, 591000, 592000, 593000, 594000, 595000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 905000, 907000, 909000, 910000, 912000, 916000, 920000, 921000, 922000, 923000, 926000, 928000, 930100, 930200, 931000 47,956,410 
7 Support - President/CEO Entergy Services, LLC 107000, 174101, 183KSL, 184001, 408110, 426500, 514000, 560000, 566000, 568000, 580000, 588000, 903001, 903002, 905000, 907000, 908000, 909000, 910000, 911000, 912000, 913000, 916000, 920000, 921000, 922000, 923000, 926000, 928000, 930100, 930200, 931000, 935000 7,779,098 
8 Loaned Labor and Associated Loaders Entergy Arkansas, LLC 107000, 108230, 408110, 562000, 588000, 592000, 593000, 594000, 596000, 598000, 903002, 926000, 926NS1 110,418 
9 Storm Support Entergy Arkansas, LLC 174101, 228100 608,687 
10 Loaned Labor and Associated Loaders Entergy Louisiana, LLC 107000, 408110, 502000, 512000, 513000, 514000, 549000, 553000 ,566000, 568000, 583000, 586000, 593000, 594000, 596000, 598000, 902000, 903002, 920000, 922000, 926000, 926NS1 385,266 
11 Storm Support Entergy Louisiana, LLC 174101, 228100 1,089,443 
12 Non-power Goods or Services Provided for Affiliate
13 Loaned Labor and Associated Loaders Entergy Louisiana, LLC 107000,118001,184001 ,228400, 408110, 513000, 563000, 568000, 570000,580000, 586000, 587000, 588000, 592000, 593000, 594000, 596000, 878000, 902000, 903001, 920000, 922000, 926000, 926NS1 134,541 
14 Storm Support Entergy Louisiana, LLC 174101 706,638 
(b) Concept: DescriptionOfNonPowerGoodOrService
Listed below are the allocation factors used to allocate costs to the affiliate.
Note: Where no allocation factor is provided for the non-power goods or services listed on Schedule 429, the costs associated with those goods and services were directly charged and not allocated.

Description of the Non-Power Good or Service Cost Allocator(s)
Entergy Services
Support - Corporate APPSUNIX, APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, BNKACCTA, CAPACCGT, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DIRCTEMI, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, EMPXENUC, GENLDREG, GENLEDAL, GPASSTAL, GWHOPCPE, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCPSPXNC, SCRSPALL, SCTDSPAL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - Finance and Accounting APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DIRCTEMI, DSTLNALL, EMPLOREG, EMPLOYAL, EMPLPRES, GENLDREG, GENLEDAL, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PKLOADAL, PRCHKALL, SCDSPALL, SCMATRAN, SCPSPALL, SCRSPALL, SQFTALLC, TRANSPND, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - Power Generation ARTRNALL, ASSTSALL, ASSTSREG, CAPACCGT, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEOPCO, CUSTEGOP, DIRCTEMI, EMPLOREG, EMPLOYAL, GWHOPCPE, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, PKLOADAL, SCFSPALL, SCPSPALL, SCRSPALL, SQFTALLC, TELPHALL, TRANSPND, TRSBLNOP
Support - Information Technology APPSMVSX, APPSUNIX, APPSUPAL, ASSTSALL, ASSTSREG, CAPACCGT, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, EMPLOYAL, EMPXENUC, GENLEDAL, GWHOPCPE, ITSPENDA, LBRBILAL, LBRCORPT, LBRFDPOL, LBRINFOR, LBRLEGAL, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCPSPALL, SCPSPXNC, SCRSPALL, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLUSG
Support - Power Delivery APPSUPAL, ASSTSALL, ASSTSREG, ASTREGOP, CAPACCGT, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, DSTLNALL, EMPLFRAN, EMPLOREG, EMPLOYAL, EMPLTRAN, GENLDREG, GENLEDAL, GPASSTAL, GWHOPCPE, ITSPENDA, LBRBILAL, LBRCORPT, LBRFDPOL, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - President/CEO APPSUPAL, ASSTSALL, ASSTSREG, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, EMPLOYAL, ITSPENDA, LBRBILAL, LBRCORPT, LBRUTOPN, MACCTALL, NETPPEAL, PCNUMALL, PKLOADAL, SCMATRAN, SQFTALLC, TRSBLNOP
Cost Allocator Descriptions

Cost Allocator Cost Allocator Title Cost Allocator Description
Entergy Services
APPSMVSX Server and Mainframe Usage - MVS Based on mainframe usage
APPSUNIX Server and Mainframe Usage - UNIX Based on the UNIX server usage
APPSUPAL Server and Mainframe Usage - Composite Based on a weighted composite of UNIX and NT servers and mainframe usage
APTRNALL Accounts Payable Transactions Based on a twelve month number of accounts payable transactions processed
ARTRNALL Accounts Receivable Invoices Based on a twelve month number of accounts receivable transactions processed
ASSTSALL Total Assets Based on the total assets at period end
ASSTSREG Total Assets - Regulated BU's Based on total assets at period end for all regulated Business Units
ASTREGOP Total Assets - Regulated BUs, excluding SERI Based on total assets at period end for all regulated Business Units, excluding SERI
BNKACCTA Bank Accounts Based on the number of bank accounts at period end
CAPACCGT System Capacity - CCGT Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously (CCGT)
CAPAOPCO System Capacity Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously
CAPXCOPC System Capacity - Excluding Coal and Nuclear Based on the power level, in kilowatts, that could be achieved if all non-coal and non-nuclear generating units were operating at maximum capability simultaneously
COMCLAIM Workers' Compensation Claims Based on number of open workers' compensation claims
CUSEGAMI Customers - AMI Only Based on a twelve-month average number of electric-only, gas-only, and dual (electric and gas) customers derived from the number of gas-only customers provided by Gas Operations. This method should only be used to allocate Advanced Metering Infrastructur
CUSEGXTX Electric and Gas Customers - Excluding ETI Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, municipal, and general business customers, excluding ETI
CUSEOPCO Electric Customers Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers
CUSTCALL Customer Call Centers Based on a twenty-four month average of customer calls
CUSTEGOP Electric and Gas Customers Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, and municipal general business customers
CUSTEXTX Electric Customers - Excluding ETI Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI, ELA, EMI, and ENOI
DIRCTEMI 100% to EMI (BU M0000) Bill 100% to Entergy Mississippi, Inc. (BU M0000)
DSTLNALL Distribution Line Miles Based on the number of miles of distribution lines
EMPLFRAN Employees - Franchise Operations Based on the number of full-time and part-time employees within Franchise Operation
EMPLOCSS Employees - Customer Support Services Based on the number of full-time and part-time employees within Customer Support Service
EMPLOFOS Employees - Fossil Plant Operations Based on the number of full-time and part-time employees within Fossil Plant Operations
EMPLOREG Full-Time and Part-Time Employees - EAI, ELA, EMI, ENOI, SERI, ETI and ESI Based on the number of full-time and part-time employees at period end for EAI, ELA, EMI, ENOI, SERI, ETI and ESI
EMPLOYAL Full-Time and Part-Time Employees Based on the number of full time and part time employees at period end
EMPLPRES Employees - State President Based on the number of full-time and part-time employees within State President Organizations
EMPLTRAN Employees - Transmission Based on the number of full-time and part-time employees within Transmission
EMPLUTOP Employees - Utility Operations Based on the number of full-time and part-time employees within Utility Operations
EMPXENUC Employees - Excluding ENUC Based on the number of full-time and part-time employees at period end, excluding ENUC
GENLDREG General Ledger Transactions - Regulated Companies Based on general ledger transactions for regulated companies
GENLEDAL General Ledger Transactions Based on the general ledger transactions
GPASSTAL Gross Utility Plant Assets - OpCos (EAM use only) Based on the gross value of utility plant assets at period end for all Entergy Operating Company - for EAM (Enterprise Asset Management) use only
GWHOPCPE GWH Energy Sales Based on energy sales to ultimate customers
INSPREAL Insurance Premiums Based on non nuclear insurance premiums
ITSPENDA Information Technology Total Spending Based on Information Technology twelve-month total spending
LBRBILAL ESL Labor Costs Billed Based on total labor dollars billed to each Client Company by ESL
LBRCOMUN ESL Labor Billed - Communications Based on total labor dollars billed to each company by ESL for the Communications function
LBRCORPT ESL Labor Billed - Corporate Based on total labor dollars billed to each company by ESL for the Corporate function
LBRFDPOL ESI Labor Billed - Federal Policy, Regulatory and Governmental Affairs Based on total labor dollars billed to each company by ESI for the Federal Policy, Regulatory and Governmental Affairs function
LBRFINAN ESL Labor Billed - Finance Based on total labor dollars billed to each company by ESL for the Finance function
LBRINFOR ESL Labor Billed - IT Based on total labor dollars billed to each company by ESL for the IT function
LBRLEGAL ESL Labor Billed - Legal Based on total labor dollars billed to each company by ESL for the Legal function
LBRSUPCN ESI Labor Billed - Supply Chain Based on total labor dollars billed to each company by ESI for the Supply Chain function
LBRUTOPN ESI Labor Billed - Utility Operations Based on total labor dollars billed to each company by ESI for the Utility Operations function
LVLSVCAL ESL Service Level Based on ESL total billings to each Client Company
MACCTALL Managed Accounts Based on number of retail managed accounts
NETPPEAL Net Property, Plant, and Equipment Based on the net book value of all companies with property, plant and equipment - excluding natural gas and nuclear fuel
OWNISFI Percentage Ownership - SFI Based on the percentage ownership of SFI
PCNUMALL Number of PC's Based on the number of PC's within each Business Unit
PCNUMXNR Number of PC's - Excluding Non-Regulated BU's Based on the number of PC's within each regulated Business Unit at EAI, ELA, EMI, ENOI, SERI, ETI and ESI
PKLOADAL Peak Load Ratio Based on the ratio of each Client Company’s load to the peak load at time of all companies peak load. The calculation of Peak Load Ratio is performed using a twelve-month rolling average of the coincident peaks.
PRCHKALL Payroll Checks Issued Based on the number of payroll checks issued for each Business Unit
RADIOALL Radio Usage Based on usage of Entergy's 2-way radio system
RECDMGNT Records Management Based on the number of full-time and part time employees at period end, excluding the Nuclear function using records management services
SCDSPALL Supply Chain Spending - Distribution Based on Supply Chain Procurement Total Spending for the Distribution Function
SCFSPALL Supply Chain Spending - Fossil Based on Supply Chain Procurement Total Spending for the Fossil Function
SCMATRAN Supply Chain Transactions in Passport Based on the number of Supply Chain materials transactions for each Business Unit in Passport
SCPSPALL Supply Chain Total Spending Based on Supply Chain's Procurement Total Spending
SCPSPXNC Supply Chain Spending - Excluding Nuclear Based on Supply Chain Procurement Total Spending, excluding Nuclear for twelve months
SCRSPALL Supply Chain Spending - Regulated Companies Based on Supply Chain Procurement Total Spending for the Regulated Companies
SCTDSPAL Supply Chain Spending - Distribution and Transmission Based on Supply Chain's Procurement Total Spending for Distribution and Transmission functions
SCTSPALL Supply Chain Spending - Transmission Based on Supply Chain's Procurement Total Spending for Transmission
SQFTALLC Square Footage - All Companies Based on square footage for all Business Units
TELPHALL Number of Telephones Based on number of telephones within each Business Unit
TRALINOP Transmission Line Miles Based on the number of miles of transmission lines, weighted for design voltage (Voltage < 400kv = 1; Voltage >400kv =2)
TRANSPND Transmission Budgeted Capital Expenditures Based on Transmission Budgeted Capital Expenditures
TRASUBOP Transmission Substations Based on the number of high voltage substations weighted for Voltage (Voltage < 500kv = 1; Voltage >= 500kv = 2)
TRSBLNOP Transmission Line Miles/Substation Based on two components: Transmission Line Miles (30% weighting) and the Number of High Voltage Substations (70% weighting)
VEHCLFOS Number of Vehicles - Fossil Based on the number of vehicles owned or leased by each Business Unit for the Fossil function only
VEHCLUSG Number of Vehicles - Excluding Fossil and Nuclear Based on the number of vehicles owned or leased by each Business Unit that participates in the usage based transportation allocation, excluding Fossil and Nuclear
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